|
FERC FINANCIAL REPORT
|
||
|
These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
|
||
|
Exact Legal Name of Respondent (Company) |
Year/Period of Report End of: |
|
Schedules |
Pages |
| Comparative Balance Sheet | 110-113 |
| Statement of Income | 114-117 |
| Statement of Retained Earnings | 118-119 |
| Statement of Cash Flows | 120-121 |
| Notes to Financial Statements | 122-123 |
| FERC FORM NO.
REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER |
||||
|
IDENTIFICATION |
||||
|
01 Exact Legal Name of Respondent
|
02 Year/ Period of Report
End of: |
|||
|
03 Previous Name and Date of Change (If name changed during year)
/
|
||||
|
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)
|
||||
|
05 Name of Contact Person
|
06 Title of Contact Person
|
|||
|
07 Address of Contact Person (Street, City, State, Zip Code)
|
||||
|
08 Telephone of Contact Person, Including Area Code
|
09 This Report is An Original / A Resubmission
(1)
☑ An Original ☐ A Resubmission |
10 Date of Report (Mo, Da, Yr)
|
||
| Annual Corporate Officer Certification | ||||
| The undersigned officer certifies that: I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts. | ||||
|
03 Signature
|
04 Date Signed (Mo, Da, Yr)
|
||
| Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction. | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
LIST OF SCHEDULES (Electric Utility) |
|||
|
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". |
|||
| Line No. |
Title of Schedule (a) |
Reference Page No. (b) |
Remarks (c) |
|
ScheduleIdentificationAbstract Identification |
1 | ||
|
ScheduleListOfSchedulesAbstract List of Schedules |
2 | ||
|
1 |
ScheduleGeneralInformationAbstract General Information |
101 | |
|
2 |
ScheduleControlOverRespondentAbstract Control Over Respondent |
102 | |
|
3 |
ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent |
103 | |
|
4 |
ScheduleOfficersAbstract Officers |
104 | |
|
5 |
ScheduleDirectorsAbstract Directors |
105 | |
|
6 |
ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates |
106 | |
|
7 |
ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year |
108 | |
|
8 |
ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet |
110 | |
|
9 |
ScheduleStatementOfIncomeAbstract Statement of Income for the Year |
114 | |
|
10 |
ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year |
118 | |
|
12 |
ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows |
120 | |
|
12 |
ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements |
122 | |
|
13 |
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities |
122a | |
|
14 |
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep |
200 | |
|
15 |
ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials |
202 | |
|
16 |
ScheduleElectricPlantInServiceAbstract Electric Plant in Service |
204 | |
|
17 |
ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others |
213 | |
|
18 |
ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use |
214 | |
|
19 |
ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric |
216 | |
|
20 |
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant |
219 | |
|
21 |
ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies |
224 | |
|
22 |
ScheduleMaterialsAndSuppliesAbstract Materials and Supplies |
227 | |
|
23 |
ScheduleAllowanceInventoryAbstract Allowances |
228 | |
|
24 |
ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses |
230a | |
|
25 |
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs |
230b | |
|
26 |
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs |
231 | |
|
27 |
ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets |
232 | |
|
28 |
ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits |
233 | |
|
29 |
ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes |
234 | |
|
30 |
ScheduleCapitalStockAbstract Capital Stock |
250 | |
|
31 |
ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital |
253 | |
|
32 |
ScheduleCapitalStockExpenseAbstract Capital Stock Expense |
254b | |
|
33 |
ScheduleLongTermDebtAbstract Long-Term Debt |
256 | |
|
34 |
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax |
261 | |
|
35 |
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year |
262 | |
|
36 |
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits |
266 | |
|
37 |
ScheduleOtherDeferredCreditsAbstract Other Deferred Credits |
269 | |
|
38 |
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property |
272 | |
|
39 |
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property |
274 | |
|
40 |
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other |
276 | |
|
41 |
ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities |
278 | |
|
42 |
ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues |
300 | |
|
43 |
ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1) |
302 | |
|
44 |
ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules |
304 | |
|
45 |
ScheduleSalesForResaleAbstract Sales for Resale |
310 | |
|
46 |
ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses |
320 | |
|
47 |
SchedulePurchasedPowerAbstract Purchased Power |
326 | |
|
48 |
ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others |
328 | |
|
49 |
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs |
331 | |
|
50 |
ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others |
332 | |
|
51 |
ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric |
335 | |
|
52 |
ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
336 | |
|
53 |
ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses |
350 | |
|
54 |
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities |
352 | |
|
55 |
ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages |
354 | |
|
56 |
ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses |
356 | |
|
57 |
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements |
397 | |
|
58 |
SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services |
398 | |
|
59 |
ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load |
400 | |
|
60 |
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load |
400a | |
|
61 |
ScheduleElectricEnergyAccountAbstract Electric Energy Account |
401a | |
|
62 |
ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output |
401b | |
|
63 |
ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics |
402 | |
|
64 |
ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics |
406 | |
|
65 |
SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics |
408 | |
|
66 |
ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages |
410 | |
|
0 |
ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants) |
414 | |
|
67 |
ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages |
422 | |
|
68 |
ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year |
424 | |
|
69 |
ScheduleSubstationsAbstract Substations |
426 | |
|
70 |
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies |
429 | |
|
71 |
FootnoteDataAbstract Footnote Data |
450 | |
|
StockholdersReportsAbstract Stockholders' Reports (check appropriate box) |
|||
|
Stockholders' Reports Check appropriate box:
☐ Two copies will be submitted ☐ No annual report to stockholders is prepared |
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
GENERAL INFORMATION |
|||
|
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.
|
|||
|
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.
|
|||
|
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.
|
|||
|
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.
|
|||
|
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
☐ Yes
(2)
☑ No |
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CONTROL OVER RESPONDENT |
||||
|
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust. |
||||
|
|
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CORPORATIONS CONTROLLED BY RESPONDENT |
||||
|
||||
| Line No. |
NameOfCompanyControlledByRespondent Name of Company Controlled (a) |
CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b) |
VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c) |
FootnoteReferences Footnote Ref. (d) |
| 1 | ||||
| 2 | ||||
| 3 | ||||
| 4 | ||||
| 5 | ||||
| 6 | ||||
| 7 | ||||
| 8 | ||||
| 9 | ||||
| 10 | ||||
| 11 | ||||
| 12 | ||||
| 13 | ||||
| 14 | ||||
| 15 | ||||
| 16 | ||||
| 17 | ||||
| 18 | ||||
| 19 | ||||
| 20 | ||||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OFFICERS |
|||||
|
|||||
| Line No. |
OfficerTitle Title (a) |
OfficerName Name of Officer (b) |
OfficerSalary Salary for Year (c) |
DateOfficerIncumbencyStarted Date Started in Period (d) |
DateOfficerIncumbencyEnded Date Ended in Period (e) |
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
DIRECTORS |
|||||
|
|||||
| Line No. |
NameAndTitleOfDirector Name (and Title) of Director (a) |
PrincipalBusinessAddress Principal Business Address (b) |
MemberOfTheExecutiveCommittee Member of the Executive Committee (c) |
ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d) |
|
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
INFORMATION ON FORMULA RATES |
|||
|
Does the respondent have formula rates? |
☐ Yes ☐ No |
||
|
|||
| Line No. |
RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a) |
ProceedingDocketNumber FERC Proceeding (b) |
|
| 1 | |||
| 2 | |||
| 3 | |||
| 4 | |||
| 5 | |||
| 6 | |||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding |
|||||
|
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)? |
☐ Yes ☑ No (Checked by default - Not explicitly defined) |
||||
|
|||||
| Line No. |
AccessionNumber Accession No. (a) |
DocumentDate Document Date / Filed Date (b) |
DocketNumber Docket No. (c) |
DescriptionOfFiling Description (d) |
RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e) |
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
INFORMATION ON FORMULA RATES - Formula Rate Variances |
||||
|
||||
| Line No. |
PageNumberOfFormulaRateVariances Page No(s). (a) |
ScheduleOfFormulaRateVariances Schedule (b) |
ColumnOfFormulaRateVariances Column (c) |
LineNumberOfFormulaRateVariances Line No. (d) |
| 1 | ||||
| 2 | ||||
| 3 | ||||
| 4 | ||||
| 5 | ||||
| 6 | ||||
| 7 | ||||
| 8 | ||||
| 9 | ||||
| 10 | ||||
| 11 | ||||
| 12 | ||||
| 13 | ||||
| 14 | ||||
| 15 | ||||
| 16 | ||||
| 17 | ||||
| 18 | ||||
| 19 | ||||
| 20 | ||||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
| 28 | ||||
| 29 | ||||
| 30 | ||||
| 31 | ||||
| 32 | ||||
| 33 | ||||
| 34 | ||||
| 35 | ||||
| 36 | ||||
| 37 | ||||
| 38 | ||||
| 39 | ||||
| 40 | ||||
| 41 | ||||
| 42 | ||||
| 43 | ||||
| 44 | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
IMPORTANT CHANGES DURING THE QUARTER/YEAR |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
On 05/26/2021, the City of San Diego City Council voted to approve new gas and electric franchise agreements with SDG&E. Per the requirements of the City of San Diego City Charter, a second reading and vote was held on 06/08/2021, where a supermajority of the San Diego City Council confirmed their initial vote to approve these new agreements. The agreement is effective as of July 2021. This recent Council action is the subject of ongoing litigation. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
None |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
None |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
SDG&E amended its current License for space located on Beech St., extending the term six additional months, expiring 06/30/2022. Written notice was provided to Landlord on 12/30/2021 to vacate hangar 3 located at Joe Crosson Dr. effective 01/31/2022. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
In the first quarter of 2021, there were no notable changes to the Transmission System. In the second quarter of 2021, notable changes to the Transmission System included: TL654 Conductor changed from 1-750 CU to 1-1033.5 ACSR/AW (MS RACK to Z91103) Conductor changed from 1-250-CU B.S to 1-750 CU B.S (Z2153273111 to STA F RACK) TL13816 New substation San Juan Capistrano added Conductor 1-3000 KCMIL CU is added from SJC 138kv GIS to Z125642 (577 ft; 0.1 mile) Conductor 1-1033.5 ACSR/AW is added from Z125652 to Z31482 (700 ft; 0.13 miles) Conductor 1-1033.5 ACSR/AW is removed from CP Rack to Z125642 (around 650 ft; 0.12 mile). Conductor is removed from Z125642 to Z31482 (around 750 ft; .14 mile) In the third quarter of 2021, notable changes to the Transmission System included: TL6988 [Valley Center - Terra Gen] New tie line is energized on 08/03/2021 Conductor added 1-3500 KCMIL AL (.31 miles) TL6957 [Loveland – Barrett] Loveland by SWAP project WO 2989040. LL Rack to Z293865, conductor added 1-636 ACSS/AW (0.06 miles) From Z293865 to Z293866, conductor added 1-3000 KCMIL CU (0.075 miles) TL6914 [Los Coches – Loveland] Loveland by SWAP project WO2989040 From Z293865 -Z293866, conductor added 1-3000 KCMIL CU (0.075 miles) TL648 [Rancho Carmel – Poway] Replace cable pole and UG cable at RCL sub. RCL RACK - Z812075, conductor added 1-3000 KCMIL CU (.12 miles). Old conductor removed 1-1750 KCMIL AL (.10 miles) TL616 [Rancho Santa Fe – Artesian Ranch – Lake Hodges Metering Sub] Artesian 230kv expansion project. Re-route from SF -BE - LHP station to SF-ARR-LHM SUB. Substation name change Artesian Sub -> Artesian Ranch sub; Lake Hodges Pump sta. -> lake Hodges Metering sub. From Z611159 to Z61119, conductor removed 1-636 ACSR/AW (3 miles). From Z611199 to Z163663, conductor removed 1-1033.5 ACSR/AW (1.45 miles) From Z163663 to BE rack, conductor removed 1-1750 KCMIL AL (.05 miles) From Z611159 to Z254619, conductor added 1-636-ACSR/AW (2 miles); From Z254619 to ARR rack, conductor added 1-3000 KCMIL CU (.18 miles) TL6974 [Artesian Ranch – Bernardo Sub] New tie line is energized 10/13/2021 ARR RACK to Z254404, conductor added 1-3000 KCMIL CU (.15 miles) Z254404 to Z254617, conductor added 1-636 INVAR (2.15 miles) Z254617 to BE rack, conductor added 1-3000 KCMIL CU (.13 miles) In the fourth quarter of 2021, notable changes to the Transmission System included: TL23069 [DREW SWITCHARD – DW GEN 7] TL23069 newly energized 11/16/21. 1-1250 KCMIL AL is added from Drew Rack to DW GEN 7 755ft (.14 miles) WO# 5986201 TL692 [LAS PULGAS – JAPANESE MESA] Wood to steel and reconductor (WO# 2981410) Remove old conductor from LP rack to JA Rack 1-1/0 CU B.S. (6.66 miles) Add new conductor from LP rack to JA rack 1-636 ACSR/AW (6.65 miles) There were no important changes to the distribution system. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
During the first quarter of 2021, SDG&E issued commercial paper with an average daily balance of $25.8 million and a maximum outstanding balance of $156.8 million. The quarter-end balance was $129.9 million. On 03/12/2021, SDG&E paid off the $200 million 364-day term loan. During the second quarter of 2021, SDG&E issued commercial paper with an average daily balance of $353.9 million and a maximum outstanding balance of $473 million. The quarter-end balance was $437.5 million. During the third quarter of 2021, SDG&E issued commercial paper with an average daily balance of $115.9 million and a maximum outstanding balance of $388 million. The quarter-end balance was $0 million. In addition, SDG&E borrowed $375 million under a 364-day term loan, maturing 06/27/2022. During the third quarter of 2021, on 08/13/2021, SDG&E issued $750 million of 2.950% Green First Mortgage Bonds, Series WWW, due 08/15/2051. In addition, on 08/16/2021, SDG&E paid off $350 million of 3.000% First Mortgage Bonds, Series JJJ. During the fourth quarter of 2021, SDG&E issued commercial paper with an average daily balance of $174.8 million and a maximum outstanding balance of $400.8 million. The year‐end balance was $400.8 million. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
None |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
On 09/01/2021, SDG&E employees represented by the International Brotherhood of Electrical Workers (IBEW) Local 465 received a negotiated base rate increase of 3.75%, affecting 1471 employees: Total annualized base wages for represented employees in 2021 is $1.43 million above 2020 base wages. Total annualized wages for represented employees including overtime in 2021 is $1.41 million above 2020 wages including overtime. Total annualized wage increases were lower due to minimal time-and-one-half costs as a continuing effect of temporary wage concessions made related to the 2020 Pandemic Plan. Total annualized wage increases were lower due to a decrease in double time pay related to the scheduled 16-hour workday concession within the 2020 Pandemic Plan On 09/03/2021, SDG&E reached agreement with IBEW Local 465 on the Lineman Attraction and Retention Letter of Understanding. The intent of the agreement is to attract and retain qualified Journeyman Lineman to SDGE. Approximately 235 electric-side employees each received a retention payment of $22k on 10/27/2021. Total overall cost of this payment, the first of two such payments, was $5.17 million. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Please refer to the Legal Proceedings sections of the Notes to the Financial Statements on page 123.56. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
None |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Please refer to the Notes to the Financial Statements beginning on page 123.1. |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Changes in Officers:
Changes in Directors:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
N/A |
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) |
||||
| Line No. |
Title of Account (a) |
Ref. Page No. (b) |
Current Year End of Quarter/Year Balance (c) |
Prior Year End Balance 12/31 (d) |
|
1 |
UtilityPlantAbstract UTILITY PLANT |
|||
|
2 |
UtilityPlant Utility Plant (101-106, 114) |
200 |
|
|
|
3 |
ConstructionWorkInProgress Construction Work in Progress (107) |
200 |
|
|
|
4 |
UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3) |
|
|
|
|
5 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) |
200 |
(a) |
|
|
6 |
UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5) |
|
|
|
|
7 |
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1) |
202 |
||
|
8 |
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2) |
|||
|
9 |
NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3) |
|||
|
10 |
SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4) |
|||
|
11 |
NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6) |
|||
|
12 |
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) |
202 |
||
|
13 |
NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12) |
|||
|
14 |
UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13) |
|
|
|
|
15 |
OtherElectricPlantAdjustments Utility Plant Adjustments (116) |
|||
|
16 |
GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117) |
|||
|
17 |
OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS |
|||
|
18 |
NonutilityProperty Nonutility Property (121) |
|
|
|
|
19 |
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122) |
|
|
|
|
20 |
InvestmentInAssociatedCompanies Investments in Associated Companies (123) |
|||
|
21 |
InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1) |
224 |
||
|
23 |
NoncurrentPortionOfAllowances Noncurrent Portion of Allowances |
228 |
|
|
|
24 |
OtherInvestments Other Investments (124) |
|||
|
25 |
SinkingFunds Sinking Funds (125) |
|||
|
26 |
DepreciationFund Depreciation Fund (126) |
|||
|
27 |
AmortizationFundFederal Amortization Fund - Federal (127) |
|||
|
28 |
OtherSpecialFunds Other Special Funds (128) |
|
|
|
|
29 |
SpecialFunds Special Funds (Non Major Only) (129) |
|||
|
30 |
DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175) |
|
|
|
|
31 |
DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176) |
|||
|
32 |
OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31) |
|
|
|
|
33 |
CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS |
|||
|
34 |
CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130) |
|||
|
35 |
Cash Cash (131) |
|
|
|
|
36 |
SpecialDeposits Special Deposits (132-134) |
|||
|
37 |
WorkingFunds Working Fund (135) |
|
||
|
38 |
TemporaryCashInvestments Temporary Cash Investments (136) |
|||
|
39 |
NotesReceivable Notes Receivable (141) |
|||
|
40 |
CustomerAccountsReceivable Customer Accounts Receivable (142) |
|
|
|
|
41 |
OtherAccountsReceivable Other Accounts Receivable (143) |
|
|
|
|
42 |
AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) |
|
|
|
|
43 |
NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145) |
|||
|
44 |
AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146) |
|
||
|
45 |
FuelStock Fuel Stock (151) |
227 |
||
|
46 |
FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152) |
227 |
||
|
47 |
Residuals Residuals (Elec) and Extracted Products (153) |
227 |
||
|
48 |
PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154) |
227 |
|
|
|
49 |
Merchandise Merchandise (155) |
227 |
||
|
50 |
OtherMaterialsAndSupplies Other Materials and Supplies (156) |
227 |
||
|
51 |
NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157) |
202/227 |
||
|
52 |
AllowanceInventoryAndWithheld Allowances (158.1 and 158.2) |
228 |
|
|
|
53 |
NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances |
228 |
|
|
|
54 |
StoresExpenseUndistributed Stores Expense Undistributed (163) |
227 |
||
|
55 |
GasStoredCurrent Gas Stored Underground - Current (164.1) |
|
|
|
|
56 |
LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) |
|
|
|
|
57 |
Prepayments Prepayments (165) |
(b) |
(c) |
|
|
58 |
AdvancesForGas Advances for Gas (166-167) |
|||
|
59 |
InterestAndDividendsReceivable Interest and Dividends Receivable (171) |
|
|
|
|
60 |
RentsReceivable Rents Receivable (172) |
|||
|
61 |
AccruedUtilityRevenues Accrued Utility Revenues (173) |
|
|
|
|
62 |
MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174) |
|
|
|
|
63 |
DerivativeInstrumentAssets Derivative Instrument Assets (175) |
|
|
|
|
64 |
DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175) |
|
|
|
|
65 |
DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176) |
|||
|
66 |
DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176) |
|||
|
67 |
CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66) |
|
|
|
|
68 |
DeferredDebitsAbstract DEFERRED DEBITS |
|||
|
69 |
UnamortizedDebtExpense Unamortized Debt Expenses (181) |
|
|
|
|
70 |
ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1) |
230a |
||
|
71 |
UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2) |
230b |
||
|
72 |
OtherRegulatoryAssets Other Regulatory Assets (182.3) |
232 |
|
|
|
73 |
PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183) |
|
|
|
|
74 |
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1) |
|||
|
75 |
OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2) |
|||
|
76 |
ClearingAccounts Clearing Accounts (184) |
|
|
|
|
77 |
TemporaryFacilities Temporary Facilities (185) |
|
|
|
|
78 |
MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186) |
233 |
|
|
|
79 |
DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187) |
|||
|
80 |
ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188) |
352 |
||
|
81 |
UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189) |
|
|
|
|
82 |
AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190) |
234 |
|
|
|
83 |
UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191) |
|||
|
84 |
DeferredDebits Total Deferred Debits (lines 69 through 83) |
|
|
|
|
85 |
AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reclassification as of 12/2021 Accum. Provision for Depreciation & Amortization for Ratemaking
Accumulated Provision for Depreciation & Amortization Classified
under FERC Seven Factor Test
In Accordance with Guidelines in FERC Order 888
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: Prepayments | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: Prepayments | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) |
||||
| Line No. |
Title of Account (a) |
Ref. Page No. (b) |
Current Year End of Quarter/Year Balance (c) |
Prior Year End Balance 12/31 (d) |
|
1 |
ProprietaryCapitalAbstract PROPRIETARY CAPITAL |
|||
|
2 |
CommonStockIssued Common Stock Issued (201) |
250 |
|
|
|
3 |
PreferredStockIssued Preferred Stock Issued (204) |
250 |
||
|
4 |
CapitalStockSubscribed Capital Stock Subscribed (202, 205) |
|||
|
5 |
StockLiabilityForConversion Stock Liability for Conversion (203, 206) |
|||
|
6 |
PremiumOnCapitalStock Premium on Capital Stock (207) |
|
|
|
|
7 |
OtherPaidInCapital Other Paid-In Capital (208-211) |
253 |
|
|
|
8 |
InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212) |
252 |
||
|
9 |
DiscountOnCapitalStock (Less) Discount on Capital Stock (213) |
254 |
||
|
10 |
CapitalStockExpense (Less) Capital Stock Expense (214) |
254b |
|
|
|
11 |
RetainedEarnings Retained Earnings (215, 215.1, 216) |
118 |
|
|
|
12 |
UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1) |
118 |
||
|
13 |
ReacquiredCapitalStock (Less) Reaquired Capital Stock (217) |
250 |
||
|
14 |
NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218) |
|||
|
15 |
AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219) |
122(a)(b) |
|
|
|
16 |
ProprietaryCapital Total Proprietary Capital (lines 2 through 15) |
|
|
|
|
17 |
LongTermDebtAbstract LONG-TERM DEBT |
|||
|
18 |
Bonds Bonds (221) |
256 |
|
|
|
19 |
ReacquiredBonds (Less) Reaquired Bonds (222) |
256 |
||
|
20 |
AdvancesFromAssociatedCompanies Advances from Associated Companies (223) |
256 |
||
|
21 |
OtherLongTermDebt Other Long-Term Debt (224) |
256 |
||
|
22 |
UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225) |
|||
|
23 |
UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226) |
|
|
|
|
24 |
LongTermDebt Total Long-Term Debt (lines 18 through 23) |
|
|
|
|
25 |
OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES |
|||
|
26 |
ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227) |
|
|
|
|
27 |
AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1) |
|||
|
28 |
AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2) |
|
|
|
|
29 |
AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3) |
|
|
|
|
30 |
AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4) |
|
||
|
31 |
AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229) |
|||
|
32 |
LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities |
|
|
|
|
33 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges |
|||
|
34 |
AssetRetirementObligations Asset Retirement Obligations (230) |
|
|
|
|
35 |
OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34) |
|
|
|
|
36 |
CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES |
|||
|
37 |
NotesPayable Notes Payable (231) |
|
|
|
|
38 |
AccountsPayable Accounts Payable (232) |
|
|
|
|
39 |
NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233) |
|||
|
40 |
AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234) |
|
|
|
|
41 |
CustomerDeposits Customer Deposits (235) |
|
|
|
|
42 |
TaxesAccrued Taxes Accrued (236) |
262 |
|
(a) |
|
43 |
InterestAccrued Interest Accrued (237) |
|
|
|
|
44 |
DividendsDeclared Dividends Declared (238) |
|||
|
45 |
MaturedLongTermDebt Matured Long-Term Debt (239) |
|||
|
46 |
MaturedInterest Matured Interest (240) |
|||
|
47 |
TaxCollectionsPayable Tax Collections Payable (241) |
|
|
|
|
48 |
MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242) |
|
|
|
|
49 |
ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243) |
|
|
|
|
50 |
DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244) |
|
|
|
|
51 |
LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities |
|
|
|
|
52 |
DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245) |
|||
|
53 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges |
|||
|
54 |
CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53) |
|
|
|
|
55 |
DeferredCreditsAbstract DEFERRED CREDITS |
|||
|
56 |
CustomerAdvancesForConstruction Customer Advances for Construction (252) |
|
|
|
|
57 |
AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255) |
266 |
|
|
|
58 |
DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256) |
|||
|
59 |
OtherDeferredCredits Other Deferred Credits (253) |
269 |
|
|
|
60 |
OtherRegulatoryLiabilities Other Regulatory Liabilities (254) |
278 |
|
|
|
61 |
UnamortizedGainOnReacquiredDebt Unamortized Gain on Reaquired Debt (257) |
|||
|
62 |
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281) |
272 |
||
|
63 |
AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282) |
|
|
|
|
64 |
AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283) |
|
|
|
|
65 |
DeferredCredits Total Deferred Credits (lines 56 through 64) |
|
|
|
|
66 |
LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: TaxesAccrued |
Note 1:
Ad Valorem taxes are allocated based on type of assets in each taxing jurisdiction.
Note 2:
Sales and Use taxes are allocated based on the Common Allocation Factor.
Sales and Use tax adjustments in column "f" are to adjust carry forward balances from last year.
Note 3:
State and Franchise Tax and Federal Income Tax are charged to departments based on total taxable income generated by each department.
Note 4:
Retirement, Unemployment, and Medicare taxes are charged to departments as a percentage of total taxable labor charged.
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF INCOME |
|||||||||||||
|
Quarterly
Annual or Quarterly if applicable
|
|||||||||||||
| Line No. |
Title of Account (a) |
(Ref.) Page No. (b) |
Total Current Year to Date Balance for Quarter/Year (c) |
Total Prior Year to Date Balance for Quarter/Year (d) |
Current 3 Months Ended - Quarterly Only - No 4th Quarter (e) |
Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f) |
Electric Utility Current Year to Date (in dollars) (g) |
Electric Utility Previous Year to Date (in dollars) (h) |
Gas Utiity Current Year to Date (in dollars) (i) |
Gas Utility Previous Year to Date (in dollars) (j) |
Other Utility Current Year to Date (in dollars) (k) |
Other Utility Previous Year to Date (in dollars) (l) |
|
|
1 |
UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME |
||||||||||||
|
2 |
OperatingRevenues Operating Revenues (400) |
300 |
(a) |
(f) |
|
|
|
|
(j) |
(n) |
|||
|
3 |
OperatingExpensesAbstract Operating Expenses |
||||||||||||
|
4 |
OperationExpense Operation Expenses (401) |
320 |
(b) |
(g) |
|
|
|
|
(k) |
(o) |
|||
|
5 |
MaintenanceExpense Maintenance Expenses (402) |
320 |
|
|
|
|
|
|
|||||
|
6 |
DepreciationExpense Depreciation Expense (403) |
336 |
|
|
|
|
|
|
(l) |
(p) |
|||
|
7 |
DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1) |
336 |
|||||||||||
|
8 |
AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405) |
336 |
|
|
|
|
|
|
|||||
|
9 |
AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406) |
336 |
|
|
|
|
|||||||
|
10 |
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407) |
||||||||||||
|
11 |
AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2) |
||||||||||||
|
12 |
RegulatoryDebits Regulatory Debits (407.3) |
|
|
|
|
|
|
||||||
|
13 |
RegulatoryCredits (Less) Regulatory Credits (407.4) |
||||||||||||
|
14 |
TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1) |
262 |
|
|
|
|
|
|
(m) |
(q) |
|||
|
15 |
IncomeTaxesOperatingIncome Income Taxes - Federal (409.1) |
262 |
|
|
|
|
|
|
|||||
|
16 |
IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1) |
262 |
|
|
|
|
|
|
|||||
|
17 |
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1) |
234, 272 |
|
|
|
|
|
|
|||||
|
18 |
ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1) |
234, 272 |
|
|
|
|
|
|
|||||
|
19 |
InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4) |
266 |
|
|
|
|
|
||||||
|
20 |
GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6) |
||||||||||||
|
21 |
LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7) |
||||||||||||
|
22 |
GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8) |
||||||||||||
|
23 |
LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9) |
||||||||||||
|
24 |
AccretionExpense Accretion Expense (411.10) |
||||||||||||
|
25 |
UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24) |
|
|
|
|
|
|
|
|
||||
|
27 |
NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25) |
|
|
|
|
|
|
|
|
||||
|
28 |
OtherIncomeAndDeductionsAbstract Other Income and Deductions |
||||||||||||
|
29 |
OtherIncomeAbstract Other Income |
||||||||||||
|
30 |
NonutilityOperatingIncomeAbstract Nonutilty Operating Income |
||||||||||||
|
31 |
RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415) |
||||||||||||
|
32 |
CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416) |
||||||||||||
|
33 |
RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417) |
||||||||||||
|
34 |
ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1) |
|
|
||||||||||
|
35 |
NonoperatingRentalIncome Nonoperating Rental Income (418) |
|
|
||||||||||
|
36 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1) |
119 |
|||||||||||
|
37 |
InterestAndDividendIncome Interest and Dividend Income (419) |
|
|
||||||||||
|
38 |
AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1) |
(c) |
(h) |
||||||||||
|
39 |
MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421) |
|
|
||||||||||
|
40 |
GainOnDispositionOfProperty Gain on Disposition of Property (421.1) |
|
|||||||||||
|
41 |
OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40) |
|
|
||||||||||
|
42 |
OtherIncomeDeductionsAbstract Other Income Deductions |
||||||||||||
|
43 |
LossOnDispositionOfProperty Loss on Disposition of Property (421.2) |
||||||||||||
|
44 |
MiscellaneousAmortization Miscellaneous Amortization (425) |
|
|
||||||||||
|
45 |
Donations Donations (426.1) |
|
|
||||||||||
|
46 |
LifeInsurance Life Insurance (426.2) |
|
|
||||||||||
|
47 |
Penalties Penalties (426.3) |
|
|
||||||||||
|
48 |
ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4) |
|
|
||||||||||
|
49 |
OtherDeductions Other Deductions (426.5) |
|
|
||||||||||
|
50 |
OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49) |
|
|
||||||||||
|
51 |
TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions |
||||||||||||
|
52 |
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2) |
262 |
|
|
|||||||||
|
53 |
IncomeTaxesFederal Income Taxes-Federal (409.2) |
262 |
|
|
|||||||||
|
54 |
IncomeTaxesOther Income Taxes-Other (409.2) |
262 |
|
|
|||||||||
|
55 |
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2) |
234, 272 |
|
|
|||||||||
|
56 |
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2) |
234, 272 |
|
|
|||||||||
|
57 |
InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5) |
||||||||||||
|
58 |
InvestmentTaxCredits (Less) Investment Tax Credits (420) |
||||||||||||
|
59 |
TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58) |
|
|
||||||||||
|
60 |
NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59) |
|
|
||||||||||
|
61 |
InterestChargesAbstract Interest Charges |
||||||||||||
|
62 |
InterestOnLongTermDebt Interest on Long-Term Debt (427) |
|
|
||||||||||
|
63 |
AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428) |
|
|
||||||||||
|
64 |
AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1) |
|
|
||||||||||
|
65 |
AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429) |
||||||||||||
|
66 |
AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1) |
||||||||||||
|
67 |
InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430) |
||||||||||||
|
68 |
OtherInterestExpense Other Interest Expense (431) |
|
|
||||||||||
|
69 |
AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) |
(d) |
(i) |
||||||||||
|
70 |
NetInterestCharges Net Interest Charges (Total of lines 62 thru 69) |
|
|
||||||||||
|
71 |
IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70) |
|
|
||||||||||
|
72 |
ExtraordinaryItemsAbstract Extraordinary Items |
||||||||||||
|
73 |
ExtraordinaryIncome Extraordinary Income (434) |
||||||||||||
|
74 |
ExtraordinaryDeductions (Less) Extraordinary Deductions (435) |
||||||||||||
|
75 |
NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74) |
||||||||||||
|
76 |
IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3) |
262 |
|||||||||||
|
77 |
ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76) |
||||||||||||
|
78 |
NetIncomeLoss Net Income (Total of line 71 and 77) |
(e) |
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OperatingRevenues | ||||||||||||||||||||||||
| (b) Concept: OperationExpense | ||||||||||||||||||||||||
| (c) Concept: AllowanceForOtherFundsUsedDuringConstruction | ||||||||||||||||||||||||
Modification of the Allowance for Funds Used During Construction Rate
San Diego Gas and Electric (SDG&E) received FERC approval to modify its existing Allowance for Funds Used During Construction (AFUDC) rate by excluding certain short-term debt associated with the financing of the net revenue under-collections recorded in its regulatory balancing and memo accounts.
Due to COVID, SDG&E also received FERC approval to modify the AFUDC rate by allowing the use of a simple average of historical short-term debt balances for the year ended 2019, instead of current period short-term debt balances. This is effective until March 31, 2022.
During the year, the average amount of short-term debt directly related to its balancing and memo accounts net
under-collections excluded from the calculation of AFUDC rate, amount to $277.0 million. There was no short-term debt included in the calculation of the AFUDC in 2021.
During the year, the average amount of short-term debt directly related to the use of the simple average of historical short-term debt balances excluded from the calculation of AFUDC rate, amount to $6.6 million.
| ||||||||||||||||||||||||
| (d) Concept: AllowanceForBorrowedFundsUsedDuringConstructionCredit | ||||||||||||||||||||||||
Modification of the Allowance for Funds Used During Construction Rate
San Diego Gas and Electric (SDG&E) received FERC approval to modify its existing Allowance for Funds Used During Construction (AFUDC) rate by excluding certain short-term debt associated with the financing of the net revenue under-collections recorded in its regulatory balancing and memo accounts.
Due to COVID, SDG&E also received FERC approval to modify the AFUDC rate by allowing the use of a simple average of historical short-term debt balances for the year ended 2019, instead of current period short-term debt balances. This is effective until March 31, 2022.
During the year, the average amount of short-term debt directly related to its balancing and memo accounts net
under-collections excluded from the calculation of AFUDC rate, amount to $277.0 million. There was no short-term debt included in the calculation of the AFUDC in 2021.
During the year, the average amount of short-term debt directly related to the use of the simple average of historical short-term debt balances excluded from the calculation of AFUDC rate, amount to $6.6 million.
| ||||||||||||||||||||||||
| (e) Concept: NetIncomeLoss | ||||||||||||||||||||||||
| (f) Concept: OperatingRevenues | ||||||||||||||||||||||||
| (g) Concept: OperationExpense | ||||||||||||||||||||||||
| (h) Concept: AllowanceForOtherFundsUsedDuringConstruction | ||||||||||||||||||||||||
Modification of the Allowance for Funds Used During Construction Rate
San Diego Gas and Electric (SDG&E) received FERC approval to modify its existing Allowance for Funds Used During Construction (AFUDC) rate by excluding certain short-term debt associated with the financing of the net revenue under-collections recorded in its regulatory balancing and memo accounts.
Due to COVID, SDG&E also received FERC approval to modify the AFUDC rate by allowing the use of a simple average of historical short-term debt balances for the year ended 2019, instead of current period short-term debt balances. This is effective until March 31, 2022.
During the year, the average amount of short-term debt directly related to its balancing and memo accounts net under-collections excluded from the calculation of AFUDC rate, amount to $166.0 million. There was no short-term debt included in the calculation of the AFUDC in 2020.
During the year, the use of the waiver for the simple average of historical short-term debt balances excluded from the calculation of AFUDC rate did not cause any benefit.
| ||||||||||||||||||||||||
| (i) Concept: AllowanceForBorrowedFundsUsedDuringConstructionCredit | ||||||||||||||||||||||||
Modification of the Allowance for Funds Used During Construction Rate
San Diego Gas and Electric (SDG&E) received FERC approval to modify its existing Allowance for Funds Used During Construction (AFUDC) rate by excluding certain short-term debt associated with the financing of the net revenue under-collections recorded in its regulatory balancing and memo accounts.
Due to COVID, SDG&E also received FERC approval to modify the AFUDC rate by allowing the use of a simple average of historical short-term debt balances for the year ended 2019, instead of current period short-term debt balances. This is effective until March 31, 2022.
During the year, the average amount of short-term debt directly related to its balancing and memo accounts net under-collections excluded from the calculation of AFUDC rate, amount to $166.0 million. There was no short-term debt included in the calculation of the AFUDC in 2020.
During the year, the use of the waiver for the simple average of historical short-term debt balances excluded from the calculation of AFUDC rate did not cause any benefit.
| ||||||||||||||||||||||||
| (j) Concept: OperatingRevenues | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (k) Concept: OperationExpense | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (l) Concept: DepreciationExpense | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (m) Concept: TaxesOtherThanIncomeTaxesUtilityOperatingIncome | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (n) Concept: OperatingRevenues | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (o) Concept: OperationExpense | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (p) Concept: DepreciationExpense | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
| (q) Concept: TaxesOtherThanIncomeTaxesUtilityOperatingIncome | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF RETAINED EARNINGS |
||||
|
||||
| Line No. |
Item (a) |
Contra Primary Account Affected (b) |
Current Quarter/Year Year to Date Balance (c) |
Previous Quarter/Year Year to Date Balance (d) |
|
UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216) |
||||
|
1 |
UnappropriatedRetainedEarnings Balance-Beginning of Period |
|
|
|
|
2 |
ChangesAbstract Changes |
|||
|
3 |
AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439) |
|||
|
4 |
AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit |
|||
|
9 |
AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439) |
|||
|
10 |
AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit |
|||
|
10.1 |
AdjustmentsToRetainedEarningsDebit |
|||
|
15 |
AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439) |
|||
|
16 |
BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1) |
|
|
|
|
17 |
AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436) |
|||
|
22 |
AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436) |
|||
|
23 |
DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437) |
|||
|
29 |
DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437) |
|||
|
30 |
DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438) |
|||
|
30.1 |
DividendsDeclaredCommonStock |
|
|
|
|
36 |
DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438) |
|
|
|
|
37 |
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings |
|||
|
38 |
UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37) |
|
|
|
|
39 |
AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215) |
|||
|
45 |
AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215) |
|||
|
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1) |
||||
|
46 |
AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1) |
|||
|
47 |
AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46) |
|||
|
48 |
RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1) |
|
|
|
|
UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly) |
||||
|
49 |
UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit) |
|||
|
50 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1) |
|||
|
51 |
DividendsReceived (Less) Dividends Received (Debit) |
|||
|
52 |
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year |
|||
|
53 |
UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52) |
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF CASH FLOWS |
||||||||||||
|
||||||||||||
| Line No. |
Description (See Instructions No.1 for explanation of codes) (a) |
Current Year to Date Quarter/Year (b) |
Previous Year to Date Quarter/Year (c) |
|||||||||
|
1 |
NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities |
|||||||||||
|
2 |
NetIncomeLoss Net Income (Line 78(c) on page 117) |
(a) |
|
|||||||||
|
3 |
NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income: |
|||||||||||
|
4 |
DepreciationAndDepletion Depreciation and Depletion |
|
|
|||||||||
|
5 |
NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details) |
|||||||||||
|
5.1 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
5.2 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
8 |
DeferredIncomeTaxesNet Deferred Income Taxes (Net) |
|
|
|||||||||
|
9 |
InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net) |
|
|
|||||||||
|
10 |
NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables |
|
|
|||||||||
|
11 |
NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory |
|
|
|||||||||
|
12 |
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory |
|
|
|||||||||
|
13 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
|
|
|||||||||
|
14 |
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets |
|
|
|||||||||
|
15 |
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities |
|
|
|||||||||
|
16 |
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction |
|
|
|||||||||
|
17 |
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies |
|||||||||||
|
18 |
OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote): |
|||||||||||
|
18.1 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
18.2 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
18.3 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|||||||||||
|
18.4 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
|
|
|||||||||
|
22 |
NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21) |
|
|
|||||||||
|
24 |
CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities: |
|||||||||||
|
25 |
ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land): |
|||||||||||
|
26 |
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel) |
|
|
|||||||||
|
27 |
GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel |
|||||||||||
|
28 |
GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant |
|||||||||||
|
29 |
GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant |
|||||||||||
|
30 |
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction |
|
|
|||||||||
|
31 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote): |
|||||||||||
|
31.1 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription |
|||||||||||
|
34 |
CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33) |
|
|
|||||||||
|
36 |
AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d) |
|||||||||||
|
37 |
ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d) |
|||||||||||
|
39 |
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies |
|
||||||||||
|
40 |
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies |
|||||||||||
|
41 |
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to) |
|||||||||||
|
42 |
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies |
|||||||||||
|
44 |
PurchaseOfInvestmentSecurities Purchase of Investment Securities (a) |
|||||||||||
|
45 |
ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a) |
|||||||||||
|
46 |
LoansMadeOrPurchased Loans Made or Purchased |
|||||||||||
|
47 |
CollectionsOnLoans Collections on Loans |
|||||||||||
|
49 |
NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables |
|||||||||||
|
50 |
NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory |
|||||||||||
|
51 |
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation |
|||||||||||
|
52 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
|||||||||||
|
53 |
OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote): |
|||||||||||
|
53.1 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
|
|||||||||
|
53.2 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
|
|||||||||
|
53.3 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
|
|||||||||
|
53.4 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
|
|
|||||||||
|
57 |
CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55) |
|
|
|||||||||
|
59 |
CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities: |
|||||||||||
|
60 |
ProceedsFromIssuanceAbstract Proceeds from Issuance of: |
|||||||||||
|
61 |
ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b) |
|
|
|||||||||
|
62 |
ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock |
|||||||||||
|
63 |
ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock |
|||||||||||
|
64 |
OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
64.1 |
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription |
|
|
|||||||||
|
64.2 |
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription |
|||||||||||
|
66 |
NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c) |
|
|
|||||||||
|
67 |
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
67.1 |
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities |
|||||||||||
|
70 |
CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69) |
|
|
|||||||||
|
72 |
PaymentsForRetirementAbstract Payments for Retirement of: |
|||||||||||
|
73 |
PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b) |
|
|
|||||||||
|
74 |
PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock |
|||||||||||
|
75 |
PaymentsForRetirementOfCommonStockFinancingActivities Common Stock |
|||||||||||
|
76 |
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): |
|||||||||||
|
76.1 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
|||||||||||
|
76.2 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
|
||||||||||
|
78 |
NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c) |
|
||||||||||
|
80 |
DividendsOnPreferredStock Dividends on Preferred Stock |
|||||||||||
|
81 |
DividendsOnCommonStock Dividends on Common Stock |
|
|
|||||||||
|
83 |
CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81) |
|
|
|||||||||
|
85 |
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents |
|||||||||||
|
86 |
NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83) |
|
|
|||||||||
|
88 |
CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period |
|
|
|||||||||
|
90 |
CashAndCashEquivalents Cash and Cash Equivalents at End of Period |
|
|
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NetIncomeLoss |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
NOTES TO FINANCIAL STATEMENTS |
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Notes for Statement of Cash Flows:
B.Basis of Presentation and Notes to Financial Statements Beginning on page 123.3 are excerpts from the Sempra (or the parent) Annual Report on Form 10-K for the period ending December 31, 2021, as filed with the SEC on February 25, 2022. The following disclosures contain information in accordance with SEC requirements. These financial statements, included on pages 110 through 122b of this report, were prepared in accordance with the accounting requirements of FERC as set forth in the applicable Uniform System of Accounts and published accounting releases. Such requirements and published accounting releases constitute a comprehensive basis of accounting other than U.S. GAAP. The principal differences of this basis of accounting from U.S. GAAP include, but are not necessarily limited to, the accounting for and classification of: •Certain deferred income taxes and regulatory assets and liabilities •Certain assets and liabilities between current and non-current •Certain cost of removal obligations, and property reserves •Classification of interest and penalties associated with income taxes •Electricity sales for resale and purchase power expenses •Certain revenues net of related costs •Capital lease treatment of certain contracts •Certain plant in service, accumulated depreciation, and regulatory assets •Certain pension costs between other income and A&G •Certain balance sheet treatment for operating lease for U.S. GAAP purposes are reported under Property Under Capital Leases, Amortization and Capital Lease Obligations. •Certain lease expenses between depreciation, interest expenses, and other line items. •Software costs relating to cloud computing between prepaid expenses and utility plant Due to the differences between FERC and U.S. GAAP reporting requirements as mentioned above, certain amounts disclosed in Notes 1-13 may not agree to balances in the FERC financial statements. NOTE 1. SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA BASIS OF PRESENTATION This is a report of SDG&E. SDG&E’s common stock is wholly owned by Enova, which is a wholly owned subsidiary of Sempra Energy. References in this report to “we,” and “our” are to SDG&E, unless otherwise indicated by the context. Use of Estimates in the Preparation of the Financial Statements We have prepared our Financial Statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates. REGULATED OPERATIONS SDG&E’s accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, SDG&E records regulatory liabilities when the CPUC or the FERC requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires significant judgment by management and may include, but is not limited to, consideration of: •the nature of the event giving rise to the assessment •existing statutes and regulatory code •legal precedents •regulatory principles and analogous regulatory actions •testimony presented in regulatory hearings •regulatory orders •a commission-authorized mechanism established for the accumulation of costs •status of applications for rehearings or state court appeals •specific approval from a commission •historical experience FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily NDT and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities, short-term investments, and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: •quoted forward prices for commodities •time value •current market and contractual prices for the underlying instruments •volatility factors •other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and fixed-price electricity positions. CASH AND CASH EQUIVALENTS CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered. In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers, waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E is automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. As we discuss in Note 4, the CPUC authorized SDG&E to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with customer protection measures ordered by the CPUC related to the COVID-19 pandemic. In connection with a separate CPUC decision addressing residential service disconnections, SDG&E established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP, as we discuss in Note 4. In 2021, SDG&E applied, on behalf of its customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million. In the first quarter of 2022, SDG&E received and applied the amounts directly to eligible customer accounts to reduce past due balances. We provide below allowances and changes in allowances for credit losses for trade receivables and other receivables. We record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.
Allowances for credit losses are included in the Balance Sheet as follows:
CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by our credit department and overseen by our risk management committee. This oversight includes calculating current and potential credit risk on a regular basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: •prospective counterparties’ financial condition (including credit ratings) •collateral requirements •the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty •downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance in our allowances for credit losses INVENTORIES We value natural gas inventory using the last-in first-out method. As inventories are sold, differences between the last-in first-out valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent if the natural gas inventory withdrawn from storage during the year is not replaced by year end. We generally value materials and supplies at the lower of average cost or net realizable value. The components of inventories are as follows:
WILDFIRE FUND In July 2019, the Wildfire Legislation was signed into law. The Wildfire Legislation addresses certain issues related to catastrophic wildfires in the State of California and their impact on electric IOUs. The issues addressed include wildfire mitigation, cost recovery standards and requirements, a wildfire fund, a cap on liability, and the establishment of a wildfire safety board. The Wildfire Legislation provided that SDG&E would not recover the ROE on its first $215 million of fire risk mitigation capital expenditures. The Wildfire Legislation established a revised legal standard for the recovery of wildfire costs (Revised Prudent Manager Standard) and established a fund (the Wildfire Fund) designed to provide liquidity to SDG&E, PG&E and Edison to pay IOU wildfire-related claims in the event that the governmental agency responsible for determining causation determines the applicable IOU’s equipment caused the ignition of a wildfire, primary insurance coverage is exceeded and certain other conditions are satisfied. A primary purpose of the Wildfire Fund is to pool resources provided by shareholders and ratepayers of the IOUs and make those resources available to reimburse the IOUs for third-party wildfire claims incurred after July 12, 2019, the effective date of the Wildfire Legislation, subject to certain limitations. An IOU may seek payment from the Wildfire Fund for settled or adjudicated third-party damage claims arising from certain wildfires that exceed, in aggregate in a calendar year, the greater of $1 billion or the IOU’s required amount of insurance coverage as recommended by the Wildfire Fund’s administrator. Wildfire claims approved by the Wildfire Fund’s administrator will be paid by the Wildfire Fund to the IOU to the extent funds are available. These utilized funds will be subject to review by the CPUC, which will make a determination as to the degree an IOU’s conduct related to an ignition of a wildfire was prudent or imprudent. The Revised Prudent Manager Standard requires that the CPUC apply clear standards when reviewing wildfire liability losses paid when determining the reasonableness of an IOU’s conduct related to an ignition. Under this standard, the conduct under review related to the ignition may include factors within and beyond the IOU’s control, including humidity, temperature and winds. Costs and expenses may be allocated for cost recovery in full or in part. Also, under this standard, an IOU’s conduct will be deemed reasonable if a valid annual safety certification is in place at the time of the ignition, unless a serious doubt is raised, in which case the burden shifts to the utility to dispel that doubt. The IOUs will receive an annual safety certification from the CPUC if they meet various requirements. If an IOU has maintained a valid annual safety certification, to the extent it is found to be imprudent, claims will be reimbursable by the IOU to the Wildfire Fund up to a cap based on the IOU’s rate base. The aggregate requirement to reimburse the Wildfire Fund over a trailing three calendar year period is capped at 20% of the equity portion of an IOU’s electric transmission and distribution rate base in the year of the prudency determination. Based on its 2021 rate base, the liability cap for SDG&E is approximately $1.1 billion, which is adjusted annually. The liability cap will apply on a rolling three-year basis so long as future annual safety certifications are received and the Wildfire Fund has not been terminated, which could occur if funds are exhausted. Amounts in excess of the liability cap and amounts that are determined to be prudently incurred do not need to be reimbursed by an IOU to the Wildfire Fund. The Wildfire Fund does not have a specified term and coverage will continue until the assets of the Wildfire Fund are exhausted and the Wildfire Fund is terminated, in which case, the remaining funds, if any, will be transferred to California’s general fund to be used for fire risk mitigation programs. In July 2021, the CPUC approved SDG&E’s 2021 Wildfire Mitigation Plan. In July 2021, the CPUC’s Wildfire Safety Division became the OEIS under the California Natural Resources Agency. As successor to the Wildfire Safety Division, the OEIS maintains the duties and responsibilities of the former Wildfire Safety Division with respect to Wildfire Mitigation Plans. The 2021 Wildfire Mitigation Plan is effective until the OEIS approves a new plan. In December 2021, SDG&E received its 2021 wildfire safety certification from the OEIS, which is valid for 12 months from the issue date. The Wildfire Fund was initially funded up to $10.5 billion by a loan from the State of California Surplus Money Investment Fund. The loan is financed through a DWR bond, which was put in place on October 1, 2020 and is securitized through a dedicated surcharge on ratepayers’ bills attributable to the DWR. In October 2019, the CPUC adopted a decision authorizing a non-bypassable charge to be collected by the IOUs to support the anticipated DWR bond issuance authorized by AB 1054. The CPUC decision also determined that ratepayers of non-participating electrical corporations shall not pay the non-bypassable charge. The Wildfire Fund was also funded by initial shareholder contributions from the IOUs totaling $7.5 billion. SDG&E’s share was $322.5 million. The IOUs are also required to make annual shareholder contributions to the Wildfire Fund with an aggregate value of $3 billion over a 10-year period starting in 2019. SDG&E’s share is $129 million. The contributions are not subject to rate recovery. In a complaint filed in U.S. District Court for the Northern District of California in July 2019, plaintiffs seek to invalidate AB 1054 based on allegations that the legislation violates federal law. The district court and, subsequently, the U.S. Court of Appeals for the Ninth Circuit dismissed the complaint. Wildfire Fund Asset and Obligation In 2019, SDG&E recorded both a Wildfire Fund asset and a related obligation for its commitment to make shareholder contributions of $451.5 million to the Wildfire Fund, measured at present value as of July 25, 2019 (the date by which both Edison and SDG&E opted to contribute to the Wildfire Fund). SDG&E paid its initial shareholder contribution of $322.5 million to the Wildfire Fund in September 2019. SDG&E funded this contribution with proceeds from an equity contribution from Sempra. SDG&E expects to continue to make annual shareholder contributions of $12.9 million through December 31, 2028. SDG&E accretes the present value of the Wildfire Fund obligation until the liability is settled. SDG&E is amortizing the Wildfire Fund asset on a straight-line basis over the estimated period of benefit, as adjusted for utilization by the IOUs. The estimated period of benefit of the Wildfire Fund asset is 15 years and is based on several assumptions, including, but not limited to: •historical wildfire experience of each IOU in the State of California, including frequency and severity of the wildfires •the value of property potentially damaged by wildfires •the effectiveness of wildfire risk mitigation efforts by each IOU •liability cap of each IOU •IOU prudency determination levels •FERC jurisdictional allocation levels •insurance coverage levels The use of different assumptions, or changes to the assumptions used, could have a significant impact on the estimated period of benefit of the Wildfire Fund asset. We periodically evaluate the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in these assumptions. SDG&E recognizes a reduction of its Wildfire Fund asset and records a charge against earnings in the period when there is a reduction of the available coverage due to recoverable claims from any of the participating IOUs. Wildfire claims that are recoverable from the Wildfire Fund, net of anticipated or actual reimbursement to the Wildfire Fund by the responsible IOU, decrease the Wildfire Fund asset and remaining available coverage. The following table summarizes the location of balances related to the Wildfire Fund on SDG&E’s Balance Sheet and Statement of Operations.
INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. Investment tax credits from prior years are amortized to income over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, we recognize: ▪regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR. We provide additional information about income taxes in Note 6. GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS SDG&E is required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation. Many GHG allowances are allocated to us on behalf of our customers at no cost. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. We balance costs and revenues associated with the GHG program through regulatory balancing accounts. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. RENEWABLE ENERGY CERTIFICATES RECs are energy rights established by governmental agencies for the environmental and social promotion of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable energy PPAs, internal generation or separate purchases in the market to comply with the RPS Program established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with the RPS Program. The cost of RECs at SDG&E, which is recoverable in rates, is recorded in Cost of Electric Fuel and Purchased Power on the Statement of Operations. PROPERTY, PLANT AND EQUIPMENT PP&E is recorded at cost and primarily represents the buildings, equipment and other facilities used to provide natural gas and electric utility services, including construction work in progress. . Our plant costs include labor, materials and contract services and expenditures for replacement parts incurred during a major maintenance outage of a plant. In addition, the cost of utility plant includes AFUDC. Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. We discuss assets collateralized as security for certain indebtedness in Note 5.
(1)At At December 31, 2021, includes $542 in electric transmission assets and $5 in construction work in progress related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. SDG&E’s share of operating expenses is included in the Statement of Operations. Depreciation expense is computed using the straight-line method over the asset’s estimated composite useful life, the CPUC-prescribed period, or the remaining term of the site leases, whichever is shortest.
(1)Includes $292 at December 31, 2021 related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities. We finance our construction projects with debt and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of PP&E. We earn a return on the capitalized AFUDC after the utility property is placed in service and recover the AFUDC from customers over the expected useful lives of the assets. We capitalize interest costs incurred to finance capital projects that have not commenced planned principal operations. The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest.
We provide additional information about temporary adjustments to the AFUDC rate calculation in relation to the COVID-19 pandemic in Note 4. LONG-LIVED ASSETS We test long-lived assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets. Long-lived assets include intangible assets subject to amortization, but do not include investments in unconsolidated entities. A long-lived asset may be impaired when the estimated future undiscounted cash flows are less than the carrying amount of the asset. If that comparison indicates that the asset’s carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the asset. This evaluation is performed at the lowest level for which separately identifiable cash flows exist. ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record AROs for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost using the present value of the obligation at the time the asset is placed into service, and recognize that cost over the life of the related asset by depreciating the asset retirement cost and accreting the obligation until the liability is settled. We record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with U.S. GAAP and costs recovered through the rate-making process. We have recorded AROs related to various assets, including: •fuel and storage tanks •natural gas transmission and distribution systems •hazardous waste storage facilities •asbestos-containing construction materials •nuclear power facilities •electric transmission and distribution systems •energy storage systems •power generation plants The changes in ARO are as follows:
(1)SDG&E’s increase in ARO in 2021 includes $22 million due to a revised estimate related to the decommissioning of SONGS, which is offset in noncurrent Regulatory Assets. CONTINGENCIES We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and if: •information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and •the amount of the loss or a range of possible losses can be reasonably estimated. We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events. LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred and amounts are estimable. COMPREHENSIVE INCOME Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including: •certain hedging activities •changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans The Statement of Comprehensive Income (Loss) show the changes in the components of OCI. The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income.
(1)All amounts are net of income tax, if subject to tax. (2)Pension and Other Postretirement Benefits and Total AOCI include $6 in transfers of liabilities from SDG&E to SoCalGas and $3 in transfers of liabilities from SDG&E to Sempra in 2020 related to the nonqualified pension plans.
(1)Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” in Note 7). REVENUES See Note 3 for a description of significant accounting policies for revenues. OPERATION AND MAINTENANCE EXPENSES Operation and Maintenance includes O&M and general and administrative costs, consisting primarily of personnel costs, purchased materials and services, insurance, rent and litigation expense. TRANSACTIONS WITH AFFILIATES We summarize amounts due from and to unconsolidated affiliates in the following table.
(1)SDG&E is included in the consolidated income tax return of Sempra, and its income tax expense is computed as an amount equal to that which would result from having always filed a separate return.. The following table summarizes revenues and cost of sales from unconsolidated affiliates.
Sempra, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Also, from time-to-time, SDG&E may make short-term advances of surplus cash to Sempra at interest rates based on the federal funds effective rate plus a margin of 13 to 20 bps, depending on the loan balance. SoCalGas provides natural gas transportation and storage services for SDG&E and charges SDG&E for such services monthly. SoCalGas records revenues and SDG&E records a corresponding amount to cost of sales. SDG&E and SoCalGas charge one another, as well as other Sempra affiliates, for shared asset depreciation. SoCalGas and SDG&E record revenues and the affiliates record corresponding amounts to O&M. The natural gas supply for SDG&E’s core natural gas customers is purchased by SoCalGas as a combined procurement portfolio managed by SoCalGas. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service; therefore, revenues and costs related to SDG&E are presented net in SoCalGas’ Statements of Operations. SDG&E has a 20-year contract for up to 155 MW of renewable power supplied from the ESJ wind power generation facility. A second 20-year contract between SDG&E and ESJ for up to 108 MW of renewable power supplied from the same facility commenced in January 2022. RESTRICTED NET ASSETS The CPUC’s regulation of SDG&E’s capital structures limits the amounts available for dividends and loans to Sempra. At December 31, 2021, Sempra could have received combined loans and dividends of approximately $798 million from SDG&E. The payment and amount of future dividends are at the discretion of SDG&E’s boards of directors. The following restrictions limit the amount of retained earnings that may be paid as common stock dividends or loaned to Sempra from SDG&E: •The CPUC requires that SDG&E’s common equity ratio be no lower than one percentage point below the CPUC-authorized percentage of its authorized capital structure. The authorized percentage at December 31, 2021 is 52%. •SDG&E has a revolving credit line that requires it to maintain a ratio of indebtedness to capitalization (as defined in the agreement) of no more than 65%, as we discuss in Note 5. Based on these restrictions, at December 31, 2021, SDG&E’s restricted net assets were $7.5 billion which could not be transferred to Sempra. OTHER INCOME, NET Other Income, Net on the Statement of Operations consists of the following:
NOTE 2. NEW ACCOUNTING STANDARDS No recent accounting pronouncements have had or may have a significant effect on our financial condition, results of operations, cash flows or disclosures. NOTE 3. REVENUES The following table disaggregates our revenues from contracts with customers by major service line and market. The majority of our revenue is recognized over time.
REVENUES FROM CONTRACTS WITH CUSTOMERS Our revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity service is provided to our customers and we invoice our customers for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Our performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of our performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in our customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, we pay franchise fees to operate in various municipalities and bill these franchise fees to our customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of our ability to collect from the customer, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues include the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill our customers are based on tariffs set by regulators within the respective state or country. For SDG&E, which follows the provisions of U.S. GAAP governing rate-regulated operations as we discuss in Note 1, amounts that it bills to customers also include adjustments for previously recognized regulatory revenues. We recognize revenues based on regulator-approved revenue requirements, which allow us to recover reasonable operating costs and provides the opportunity to realize our authorized rates of return on our investments. While our revenues are not affected by actual sales volumes, the pattern of our revenue recognition during the year is affected by seasonality. We recognize annual authorized revenue for customers using seasonal factors established in applicable proceedings, which generally results in a significant portion of operating revenues being recognized in the third quarter of each year. We have an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. We recognize revenues from the sale of allocated California GHG emissions allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and we have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. We balance costs and revenues associated with the GHG program through regulatory balancing accounts. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below.
(1)Excludes intercompany transactions. Contract Balances from Revenues from Contracts with Customers From time to time, we receive payments in advance of satisfying the performance obligations associated with customer contracts. We defer such revenues as contract liabilities and recognize them in earnings as the performance obligations are satisfied. Activities within our contract liabilities are presented below.
(1)Balances at December 31, 2021, 2020 and 2019 include $4, $4 and $4, respectively, in Other Current Liabilities and $79, $83 and $87, respectively, in Deferred Credits and Other. Receivables from Revenues from Contracts with Customers The table below shows receivable balances associated with revenues from contracts with customers on our Balance Sheet.
(1)Amount is presented net of amounts due to unconsolidated affiliates on the Balance Sheet, when right of offset exists. In connection with the COVID-19 pandemic and at the direction of the CPUC, we implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers, waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, we are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. In 2021, we applied, on behalf of our customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million. In the first quarter of 2022, we received and applied the amounts directly to eligible customer accounts to reduce past due balances. REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled revenues. As discussed earlier, the regulatory framework requires SDG&E to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for SDG&E to use a “decoupling” mechanism, which allows it to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive mechanisms. The CPUC applies performance-based measures and incentive mechanisms to all California IOUs, under which SDG&E has earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC and the FERC authorize SDG&E to collect revenue requirements for operating costs and capital related costs (such as depreciation, taxes and return on rate base) from customers, including: ▪costs to purchase natural gas and electricity; ▪costs associated with administering public purpose, demand response, and customer energy efficiency programs; ▪other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded within a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met at the time the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund for programs authorized, including limitations on the total cost of the program, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in disallowances of recovery from ratepayers. We discuss balancing accounts and their effects further in Note 4. NOTE 4. REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset.
(1)At December 31, 2021 and 2020, the noncurrent portion of regulatory balancing accounts – net undercollected was $358 million and $139 million, respectively. (2)Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. Regulatory Assets Not Earning a Return ▪Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. The related amounts are recovered in rates once these contracts are settled, generally within two years. ▪Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E expects to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include excess deferred income taxes resulting from statutory income tax rate changes and certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 6. ▪Regulatory assets/liabilities related to pension and other postretirement benefit plan obligations are offset by corresponding liabilities/assets. The assets are recovered in rates as the plans are funded. ▪The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 48-year period. Regulatory Assets Earning a Return ▪Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized amounts. Depreciation, taxes and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. The adopted revenue requirements in the 2019 GRC FD associated with the period from January 1, 2019 through December 31, 2019 were recovered in rates over a 24-month period that began in January 2020. Amortization expense on certain regulatory assets for the years ended December 31, 2021, 2020 and 2019 was $5 million, $4 million and $3 million, respectively. COVID-19 Pandemic Protections In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers, waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E is automatically enrolling residential and small business customers with past-due balances in long-term repayment plans. In 2021, SDG&E applied, on behalf of its customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million. In the first quarter of 2022, SDG&E received and applied the amounts directly to eligible customer accounts to reduce past due balances. SDG&E has been authorized to track and request recovery of incremental costs associated with complying with customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from customers’ failure to pay. We expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in future CPUC proceedings, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below. Disconnection OIR In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. As permitted by the decision, SDG&E has established a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. CPUC GRC The CPUC uses GRCs to set rates designed to allow SDG&E to recover reasonable operating costs and to provide the opportunity to realize authorized rates of return on its investments. In September 2019, the CPUC issued a final decision in the 2019 GRC approving SDG&E’s test year revenues for 2019 and attrition year adjustments for 2020 and 2021, which was effective retroactively to January 1, 2019. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD approved a test year 2019 revenue requirement of $1,990 million for SDG&E’s combined operations ($1,590 million for its electric operations and $400 million for its natural gas operations). The increases include separately authorized components for O&M and capital-related costs, as follows:
In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs and SDG&E was directed to file a petition for modification to revise its 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). In May 2021, the CPUC issued a final decision approving SDG&E’s request to continue its authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. The 2019 GRC FD approved SDG&E’s establishment of two-way liability insurance premium balancing accounts, including wildfire insurance premium costs based on a specific level of coverage. The 2019 GRC FD also permits SDG&E to seek recovery of additional liability insurance coverage. The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time we released these regulatory liability balances to revenues and regulatory interest. CPUC Cost of Capital A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E that became effective on January 1, 2020 and will remain in effect through December 31, 2022, subject to the CCM.
The CCM applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E is based on its credit rating. SDG&E’s CCM benchmark rate is 4.498% based on Moody’s Baa- utility bond index. Alternatively, under the CCM, SDG&E is permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole. For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022. SDG&E is required to file its next cost of capital application in April 2022 for a January 1, 2023 effective date. FERC Rate Matters SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided for a ROE of 10.60%, consisting of a base ROE of 10.10% plus an additional 50 bps for participation in the California ISO (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar quarter until terminated by a notice at least six months before the end of the calendar year. In 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. Energy Efficiency Program Inquiry In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency Programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive. Pursuant to the CPUC ruling, intervenors representing ratepayers questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review, SDG&E concluded that some concessions were appropriate, which include refunding certain costs to customers and reducing certain performance-based incentives. Accordingly, in the year ended December 31, 2020, SDG&E reduced revenues by $51 million and recorded a fine of $6 million in Other (Expense) Income, Net, on the Statement of Operations. The after-tax impact for the year ended December 31, 2020 was $44 million. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. In September 2021, the CPUC approved the settlement agreement. NOTE 5. DEBT AND CREDIT FACILITIES SHORT-TERM DEBT Committed Line of Credit At December 31, 2021, SDG&E had an aggregate capacity of $1.5 billion from a committed line of credit, which provides liquidity and support our commercial paper program. Because our commercial paper program is supported by the line of credit, we reflect the amount of commercial paper outstanding, before reductions of any unamortized discounts, and any letters of credit outstanding as a reduction to the available unused credit capacity.
The principal terms of our committed line of credit reflected in the table above include the following: ▪The facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in any facility. ▪The facility provides for the issuance of $100 million of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, SDG&E has the right to increase its letter of credit commitment up to $250 million. ▪Borrowings bear interest at a benchmark rate plus a margin that varies with SDG&E’s credit ratings. ▪SDG&E must maintain a ratio of indebtedness to total capitalization (as defined in the credit facility) of no more than 65% at the end of each quarter. At December 31, 2021, SDG&E was in compliance with this ratio under its credit facility. Uncommitted Letters of Credit Outside of our credit facility, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements.
Term Loan In June 2021, we entered into a $375 million, 364-day term loan with a maturity date of June 27, 2022. At December 31, 2021, $375 million, net of negligible issuance costs, was outstanding under the term loan. The borrowing bears interest at benchmark rates plus 62.5 bps. The term loan provides SDG&E with additional liquidity outside of its line of credit. WEIGHTED-AVERAGE INTEREST RATES The weighted-average interest rates on the total short-term debt at December 31 were as follows:
LONG-TERM DEBT The following table shows the detail and maturities of long-term debt outstanding:
(1)Callable long-term debt not subject to make-whole provisions
(1)Excludes finance lease obligations, discounts, and debt issuance costs. SDG&E does not have unsecured long-term obligations at December 31, 2021. Callable Long-Term Debt At our option, certain debt at December 31, 2021 is callable subject to premiums:
First Mortgage Bonds We issue first mortgage bonds secured by liens on our utility plant assets. We may issue additional first mortgage bonds if in compliance with the provisions of our bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of additional first mortgage bonds of $7.3 billion at December 31, 2021. In August 2021, we issued $750 million of 2.95% green first mortgage bonds maturing in 2051 and received proceeds of $737 million, net of debt discount, underwriting discounts and debt issuance costs of $13 million. We intend to use the net proceeds to finance or refinance eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation. Other Long-Term Debt On February 18, 2022, we entered into a $400 million, two-year term loan with a maturity date of February 18, 2024. We may request up to three borrowings for an aggregate amount of $400 million through May 18, 2022. On February 18, 2022, we borrowed $200 million. The borrowing bears interest at benchmark rates plus 62.5 bps. The margin is based on our long-term senior unsecured credit rating. NOTE 6. INCOME TAXES We provide our calculations of ETRs in the following table.
For SDG&E, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment: ▪repairs expenditures related to a certain portion of utility plant fixed assets ▪the equity portion of AFUDC, which is non-taxable ▪a portion of the cost of removal of utility plant assets ▪utility self-developed software expenditures ▪depreciation on a certain portion of utility plant assets ▪state income taxes We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs.
The remeasurement of deferred income tax balances in December 2017, as a result of the TCJA, resulted in excess deferred income taxes that previously had been collected from ratepayers at the higher rate. In a January 2019 decision, the CPUC directed certain excess deferred income tax balances generated by activities outside of ratemaking be allocated to shareholders rather than ratepayers. As a result, in 2019, SDG&E recorded income tax benefits of $31 million from the release of a portion of the regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances. The table below summarizes the effects of the TCJA remeasurement at December 31, 2017, by FERC account and jurisdiction.
(1)Since the table is summarizing a reduction to the net deferred income tax liability balance, the decrease to the 190 deferred tax asset account in this table is shown as positive. (2)Does not include the net operating loss deferred tax asset related to FERC Transmission. (3)Account 283 includes approximately $500 million of gross-up required under ASC 740 on flow-through deferred taxes and gross-up on excess deferred taxes. In the first quarter of 2018, we made a $38 million true-up primarily related to the gross-up on flow-through deferred taxes required under ASC 740, Income Taxes. This resulted in additional reduction of deferred tax liabilities and an increase in net regulatory liabilities. In the first quarter of 2019, we reclassed $31 million of certain excess deferred taxes out of regulatory liabilities and into Shareholder, because these items were not related to plant in service nor were they part of the reduction to rate base for accumulated deferred income taxes. The table below represents the amount of protected and unprotected excess deferred income taxes related to plant in service (excluding gross-up) as of December 31, 2021, 2020, 2019, 2018 and 2017.
(1)Does not include the net operating loss deferred tax asset related to FERC Transmission. (2)Includes prior year true-up to excess deferred income tax balance and an adjustment to reclass certain Transmission-related excess deferred income taxes between Protected and Unprotected pursuant to FERC Order 864. (3)Includes prior true-up to excess deferred income tax balance. For plant in service, we use the Average Rate Assumption Method (ARAM) to amortize the excess deferred income taxes over the book life of the underlying property. During 2019, we received a final decision from the CPUC in our general rate case directing us to use straight-line amortization over a six-year period for certain unprotected items, and allowing us to track any differences between using ARAM and using the six-year straight-line amortization for these unprotected items. During 2021, we decided we would no longer contest the CPUC’s treatment of these unprotected items, which resulted in increased amortization in 2021. The CPUC decision also allowed us to track differences related to the inclusion of new cost of removal accruals in the ARAM calculation. As of December 31, 2021, we have not received a final regulatory order from the FERC regarding how customer rates should be reduced for excess deferred income taxes. Future potential regulatory orders and IRS guidance could impact our classification of protected and unprotected amounts indicated above, as well as the inclusion of new cost of removal accruals in the ARAM calculation. Under ARAM, we reduced our regulatory liability related to excess deferred income taxes by $19 million, $10 million, $8 million, and $9 million in 2021, 2020, 2019, and 2018 respectively, excluding gross-up. The reduction in the excess deferred income tax regulatory liability (FERC AC 254) was offset against deferred income taxes (FERC AC 411.1). The table below reflects these adjustments for the following FERC accounts as of December 31, 2021, 2020, 2019, and 2018.
3.0 The components of income tax expense are as follows.
The table below presents the components of deferred income taxes:
Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31:
(1)Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following:
Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in Income Tax Expense on the Statement of Operations. SDG&E accrued negligible amounts for interest expense and penalties at December 31, 2021 and 2020 on the Balance Sheet, and recorded negligible amounts of interest expense and penalties in the Statement of Operations for all periods presented. INCOME TAX AUDITS SDG&E is subject to U.S. federal income tax and state income tax and remains subject to examination for U.S. federal tax years after 2017 and state tax years after 2012 NOTE 7. EMPLOYEE BENEFIT PLANS For our employee benefit plans, we: •recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the balance sheet; •measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year; and •recognize changes in the funded status of pension and PBOP plans in the year in which the changes occur. Generally, those changes are reported in OCI and as a separate component of shareholders’ equity. The detailed information presented below covers the employee benefit plans of primarily Sempra and its consolidated subsidiaries. Sempra has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E, which collectively cover all eligible employees, including a member of the Sempra board of directors who was a participant in a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology. Sempra also has PBOP plans, including separate plans for SDG&E, which collectively cover all employees. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits. Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. We review these assumptions on an annual basis and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. RABBI TRUST In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $567 million and $512 million at December 31, 2021 and 2020, respectively. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS Benefit Plan Amendments Affecting 2019 In 2019, certain executive participants in a company nonqualified pension plan became eligible in this same plan for Supplemental Executive Retirement Plan benefits. This was treated as a plan amendment and increased the recorded pension liability by $3 million in 2019. Benefit Obligations and Assets The following table provides a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2021 and 2020, and a statement of the funded status at December 31, 2021 and 2020:
Actuarial losses (gains) fluctuate based on changes in assumptions that we describe below in “Assumptions for Pension and Other Postretirement Benefit Plans” and updates to census data. In 2021, 2020 and 2019, the Society of Actuaries released updated mortality improvement projection scales, reflecting changes to projected observed longevity improvements in its mortality tables. We have incorporated these assumptions, adjusted for the Sempra companies’ actual mortality experience, in our calculations for each of those years. ▪Actuarial gains in pension plans in 2021 were driven primarily by an increase in discount rates. These actuarial gains were partially offset by actuarial losses due to an increase in the interest crediting rate for the cash balance plans due to updated census data. ▪Actuarial gains in PBOP plans in 2021 were driven primarily by an increase in discount rates. Net Assets and Liabilities The assets and liabilities of the pension and PBOP plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. SDG&E recognizes realized and unrealized investment gains and losses during the current year. We use the 10% corridor accounting method. Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The 10% corridor accounting method helps mitigate volatility of net periodic benefit costs from year to year. Defined benefit pension and other postretirement plans with an aggregated overfunded status are recognized as an asset and with an aggregated underfunded status are recognized as a liability; unrecognized changes in these assets and/or liabilities are normally recorded in AOCI on the balance sheet. We record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on decisions by regulatory agencies. We record annual pension and other postretirement net periodic benefit costs equal to the contributions to our qualified plans as authorized by the CPUC. The annual contributions to the pension plans are the greater of: ▪a minimum required funding amount as required by the IRS; ▪the amount required to maintain an 85% Adjusted Funding Target Attainment Percentage as defined by the Pension Protection Act of 2006, as amended; or ▪beginning January 1, 2019 and for the duration of the 2019 GRC cycle, a fixed amount equal to the estimated annual service cost as defined by U.S. GAAP plus one year of a 14-year amortization of the unfunded projected benefit obligation of the pension plan as of January 1, 2019, and limited to an annual amount that keeps the fair value of the pension plan assets from exceeding 110% of the pension benefit obligation of the plan. The annual contributions to PBOP plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with U.S. GAAP for pension and PBOP plans. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. The net (liability) asset is included in the following categories on the Balance Sheet at December 31:
Amounts recorded in AOCI at December 31, net of income tax effects and amounts recorded as regulatory assets, are as follows:
The following table shows the obligations of funded pension plan with benefit obligations in excess of plan assets. At December 31, 2021, the assets for SDG&E’s funded pension plan exceeded the plan’s obligations.
The following table shows SDG&E’s obligations of unfunded pension plans at December 31:
SDG&E has a funded other postretirement benefit plan. At December 31, 2021, the assets for SDG&E’s other postretirement benefit plan exceeded the plan’s obligations. Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost and pretax amounts recognized in OCI for the years ended December 31:
Assumptions for Pension and Other Postretirement Benefit Plans Benefit Obligation and Net Periodic Benefit Cost We develop the discount rate assumptions using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flows to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of corporate bonds with a Bloomberg Composite of AA or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plans’ projected benefit payments discounted at this rate with the market value of the bonds selected. Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types. Interest crediting rate is based on an average 30-year Treasury bond from the month of November of the preceding year. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under U.S. GAAP. The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows:
(1)Interest crediting rate for pension benefits applies only to funded cash balance plans. (2)Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts.
(1)Interest crediting rate for pension benefits applies only to funded cash balance plans. (2)Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts. Health Care Cost Trend Rates Assumed health care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans:
Plan Assets Investment Allocation Strategy for Sempra’s Pension Master Trust Sempra’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. Sempra maintains additional trusts, as we discuss below, including for certain of SDGE’s PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks. Currently, the pension plans’ target asset allocations are: ▪31% domestic equity ▪21% international equity ▪21% long credit ▪10% diversified real assets ▪10% return-seeking credit ▪5% ultra-long duration government securities ▪2% other diversifying assets The asset allocation of the plans is reviewed by Sempra’s Plan Funding Committee and Pension and Benefits Investment Committee (the Committees) on a regular basis. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪long-term cost ▪variability and level of contributions ▪funded status ▪a range of expected outcomes over varying confidence levels This allocation results in a 74% target allocation to return-seeking assets and a 26% target allocation to risk-mitigating assets. We maintain asset allocations at strategic levels with reasonable bands of variance. In accordance with the Sempra pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on assets in our pension and PBOP plans is based on the weighted-average of the plans’ investment allocations to specific asset classes as of the measurement date. We arrive at a 6.75% expected return on assets by considering both the historical and forecasted long-term rates of return on those asset classes. We expect a return of between 4% and 12% on return-seeking assets and between 1% and 4% for risk-mitigating assets. Certain trusts that hold assets for the SDG&E other postretirement benefit plan are subject to taxation, which impacts the expected after-tax return on assets in the plan. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. Investment Strategy for SDG&E’s Other Postretirement Benefit Plans SDG&E’s PBOP plans are funded by cash contributions from SDG&E and its current retirees. The assets of these plans are placed into the pension master trust and other Voluntary Employee Beneficiary Association trusts. Certain assets of SDG&E’s PBOP plans are held in the pension master trust, which invests a portion of the assets in completion portfolios that aim to reduce interest rate risk, thereby resulting in an overall target allocation of 38% to return-seeking assets and 62% to risk-mitigating assets for these well-funded plans. SDG&E’s assets held in other Voluntary Employee Beneficiary Association trusts are invested in accordance with a de-risking glidepath that reduces the assets’ exposure to risk as the trusts become better funded. These specific allocations are periodically reviewed to help ensure that plan assets are best positioned to meet plan obligations. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in the trusts for SDG&E’s PBOP plans based on the fair value hierarchy, except for certain investments measured at NAV. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and other postretirement benefit plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Registered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices. Where the value is a quoted price in an active market, the investment is classified within Level 1 of the fair value hierarchy. Other investments are valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Certain high yield fixed-income securities are valued by applying a price adjustment to the bid side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Common/Collective Trusts – Investments in common/collective trust funds are valued based on the NAV of units owned, which is based on the current fair value of the funds’ underlying assets. Venture Capital Funds and Real Estate Funds – These funds consist of investments in venture capital funds and real estate funds that are held by limited partnerships or similar private entities following various investment strategies. The value is determined based on the NAV of our proportionate ownership interest in the entity. Derivative Financial Instruments – Futures contracts that are publicly traded in active markets are valued at closing prices as of the last business day of the year. Forward currency contracts are valued at the prevailing forward exchange rate of the underlying currencies, and unrealized gain (loss) is recorded daily. Fixed income futures and options are marked to market daily. Equity index futures contracts are valued at the last sales price quoted on the exchange on which they primarily trade. While management believes the valuation methods described above are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. We provide more discussion of fair value measurements in Notes 1 and 10. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis. SDG&E holds a proportionate share of investment assets in the pension master trust at Sempra. The fair values of our pension plan assets by asset category are as follows:
The fair values by asset category of the PBOP plan assets held in the pension master trust and in the additional trusts for SDG&E’s PBOP plan trusts are as follows:
Future Payments We expect to contribute the following amounts to our pension and PBOP plans in 2022:
The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets.
SAVINGS PLANS Sempra, SDG&E and SoCalGas offer trusteed savings plans to all employees. Employee participation, employee contributions and employer matching contributions are subject to the provisions of the respective plans, and for employee contributions, limits imposed by the respective governmental authorities. Employer contributions to the SDG&E savings plans were as follows:
The market value of Sempra common stock held by the savings plans at Sempra, SDG&E and SoCalGas was $1.0 billion and $1.1 billion at December 31, 2021 and 2020, respectively. NOTE 8. SHARE-BASED COMPENSATION SEMPRA ENERGY EQUITY COMPENSATION PLANS Sempra Energy has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra Energy. The plans permit a wide variety of share-based awards, including: •nonqualified stock options •incentive stock options •restricted stock awards •restricted stock units •stock appreciation rights •performance awards •stock payments •dividend equivalents Eligible SDG&E employees participate in Sempra’s share-based compensation plans as a component of their compensation package. In the three years ended December 31, 2021, Sempra had the following types of equity awards outstanding: ▪Nonqualified Stock Options: Options to purchase common stock have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a three-year period and expire 10 years from the date of grant. Unvested option awards are subject to forfeiture following a termination of employment, except where the retirement criteria under such awards have been met and subject to certain other exceptions described below. ▪Performance-Based Restricted Stock Units: These RSU awards generally vest in Sempra common stock at the end of three-year performance periods based on Sempra’s total return to shareholders relative to that of specified market indices or based on the compound annual growth rate of Sempra’s EPS. The comparative market indices for the awards that vest based on total return to shareholders are the S&P 500 Utilities Index (excluding water companies) and the S&P 500 Index. Sempra uses long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies (excluding water companies) to develop its targets for awards that vest based on EPS growth. These RSU awards are subject to forfeiture prior to vesting following a termination of employment, except where the retirement criteria under such awards have been met and subject to certain other exceptions described below. •Up to an additional 100% of the granted RSUs may be issued if total return to shareholders or EPS growth exceeds target levels. •For awards granted in 2016 and certain awards granted in 2017 and 2018 that vest based on Sempra’s total return to shareholders, a modifier adds 20% to the award’s payout (as initially calculated based on total return to shareholders relative to that of specified market indices) for total shareholder return performance in the top quartile relative to historical benchmark data for Sempra and reduces the award’s payout by 20% for performance in the bottom quartile. However, in no event will more than an additional 100% of the granted RSUs be issued. If performance falls within the second or third quartiles, the modifier is not triggered, and the payout is based solely on total return to shareholders relative to that of specified market indices. If Sempra’s total return to shareholders or EPS growth is below the target levels but above threshold performance levels, shares are subject to partial vesting on a pro rata basis. ▪Service-Based Restricted Stock Units: RSUs may also be service-based; these generally vest ratably over three-year service periods (for awards granted after 2018), or at the end of three-year (for awards granted during 2016 through 2018) or four-year service periods (for awards granted prior to 2015). These awards are subject to earlier forfeiture upon termination of employment, subject to certain exceptions described below. For awards that would otherwise be forfeited upon termination of employment, the Compensation and Talent Development Committee of Sempra’s board of directors may waive the forfeiture requirement and, with respect to options and service-based RSUs, may accelerate vesting. Awards are also subject to accelerated vesting upon a change in control under the applicable LTIP, in accordance with severance pay agreements or to the extent otherwise required by the terms of the applicable award. Dividend equivalents on shares subject to RSUs are reinvested to purchase additional common shares that become subject to the same vesting conditions as the RSUs to which the dividends relate. SHARE-BASED AWARDS AND COMPENSATION EXPENSE At December 31, 2021, 5,986,241 of Sempra common shares were authorized and available for future grants of share-based awards. Sempra’s practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. Sempra measures and recognizes compensation expense for all share-based payment awards made to its employees and directors based on estimated fair values on the date of grant. Sempra recognizes compensation costs net of an estimated forfeiture rate (based on historical experience) and recognizes the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three or four years. However, for awards granted to retirement-eligible participants, the expense is recognized over the initial year in which the award was granted as the award requires service through the end of the year in which it was granted. For awards granted to participants who become eligible for retirement during the requisite service period, the expense is recognized over the period between the date of grant and the later of the end of the year in which the award was granted or the date the participant first becomes eligible for retirement. Substantially all awards outstanding are classified as equity instruments; therefore, Sempra recognizes additional paid in capital as it recognizes the compensation expense associated with the awards. Sempra recognizes in earnings the tax benefits (or deficiencies) resulting from tax deductions that are in excess of (or less than) tax benefits related to compensation cost recognized for share-based payments. SDG&E records an expense for the plans to the extent that its employees participate in the Sempra plans and/or SDG&E is allocated a portion of the Sempra plans’ corporate staff costs. For SDG&E, total share-based compensation expense for share-based awards was comprised as follows:
SEMPRA NONQUALIFIED STOCK OPTIONS Sempra uses a Black-Scholes option-pricing model to estimate the fair value of each nonqualified stock option grant. The use of a valuation model requires it to make certain assumptions about selected model inputs. Expected volatility is calculated based on a blend of the historical and implied volatility of Sempra’s common stock price. The average expected term for options is based on the vesting schedule, contractual term of the option, expected employee exercise and post-termination behavior. The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected term estimated at the date of the grant. In 2021, 2020 and 2019, Sempra’s board of directors granted 222,620, 154,860 and 261,075 nonqualified stock options, respectively, that are exercisable over a three-year period. The weighted-average per- share fair value for options granted was $19.07, $19.76 and $13.20 in 2021, 2020 and 2019, respectively. To calculate this fair value, Sempra used the Black-Scholes model with the following weighted-average assumptions:
The following table shows a summary of nonqualified stock options at December 31, 2021 and activity for the year then ended:
The aggregate intrinsic value at December 31, 2021 is the total of the difference between Sempra’s closing common stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for nonqualified stock options exercised in the last three years was: ▪$1.4 million in 2021 ▪$0.4 million in 2020 ▪$4 million in 2019 Sempra expects a negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.1 years. The weighted-average per-share fair values for nonqualified stock options granted in 2020 and 2019 was $149.12 and $106.76, respectively. Sempra received cash of $5 million, a negligible amount and $3 million from stock option exercises in 2021, 2020 and 2019, respectively. SEMPRA RESTRICTED STOCK UNITS Sempra uses a Monte-Carlo simulation model to estimate the fair value of its RSUs that vest based on Sempra’s total return to shareholders. Its determination of fair value is affected by the historical volatility of the common stock price for Sempra and its peer group companies. The valuation also is affected by the risk-free rates of return and a number of other variables. Below are key assumptions for RSUs granted in the last three years:
The following table shows a summary of RSUs at December 31, 2021 and activity for the year then ended:
(1)Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra Energy exceeds target performance conditions. In 2021, 2020 and 2019, the total fair value of RSU shares vested during the year was $57 million, $70 million and $36 million, respectively. Sempra expects $17 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.5 years. The weighted-average per-share fair values for performance-based RSUs granted were $155.62 and $113.54 in 2020 and 2019, respectively. The weighted-average per-share fair values for service-based RSUs granted were $138.91 and $112.50 in 2020 and 2019, respectively. NOTE 9. DERIVATIVE FINANCIAL INSTRUMENTS We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposure is commodity market risk. Our use of derivatives for this risk is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating risks (1) that could lead to declines in anticipated revenues or increases in anticipated expenses, or (2) that could cause our asset values to fall or our liabilities to increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Balance Sheet. We may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges and undesignated derivatives not subject to rate recovery). We classify cash flows from the settlements of our derivative instruments as operating activities on the Statement of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting for derivative commodity instruments . Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetting the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: ▪We use natural gas and electricity derivatives, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed-price natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Statement of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. ▪We are allocated and may purchase CRRs, which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Statement of Operations. ▪From time to time, we may use other energy derivatives to hedge exposures such as GHG allowances. The following table summarizes net energy derivative volumes.
FINANCIAL STATEMENT PRESENTATION The Balance Sheet reflects the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Balance Sheet, including the amount of cash collateral receivables that were not offset because the cash collateral was in excess of liability positions.
(1)Included in Current Assets: Fixed-Price Contracts and Other Derivatives. The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Statement of Operations.
CONTINGENT FEATURES Certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. SDG&E did not have this group of derivative instruments in a liability position at December 31, 2021 or 2020. Some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.. NOTE 10. FAIR VALUE MEASUREMENTS RECURRING FAIR VALUE MEASURES The tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2021 and 2020. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair-valued assets and liabilities, and their placement within the fair value hierarchy. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 9 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis in the tables below include the following: ▪Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, excluding accounts receivable and accounts payable. A third-party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪For commodity contracts, we primarily use a market or income approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corroborated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard models that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long-term, fixed-price electricity positions, as we discuss below in “Level 3 Information.” ▪Rabbi Trust investments include short-term investments that consist of money market and mutual funds that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1).
(1)Excludes cash balances and cash equivalents. (2)Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. Level 3 Information The table below sets forth reconciliations of changes in the fair value of CRRs and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for SDG&E.
(1)Excludes the effect of the contractual ability to settle contracts under master netting agreements. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following year. For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below:
The impact associated with discounting is negligible. Because these auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 9. Long-term, fixed-price electricity positions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. The range and weighted-average price of these inputs at December 31 were as follows:
A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 9. Realized gains and losses associated with CRRs and long-term, fixed-price electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Statement of Operations. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, accounts receivable, short-term amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Balance Sheet.
(1)Before reductions of unamortized discount and debt issuance costs of $61 and $52 at December 31, 2021 and 2020, respectively, and excluding finance lease obligations of $1,274 and $1,276 at December 31, 2021 and 2020, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 12. NOTE 11. PREFERRED STOCK SDG&E is authorized to issue up to 45 million shares of preferred stock, respectively. At December 31, 2021 and 2020, SDG&E had no preferred stock outstanding. The rights, preferences, privileges and restrictions for any new series of preferred stock would be established by SDG&E’s board of directors at the time of issuance. NOTE 12. SAN ONOFRE NUCLEAR GENERATING STATION SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in SDG&E’s Statement of Operations. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20% of the total decommissioning cost. The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the foundation filed a notice of appeal. In September 2020, the foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the CCC’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. In December 2021, the foundation filed a request for dismissal. To date, decommissioning work has not been interrupted as a result of these writ petitions. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. Amounts that were collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Balance Sheet at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In December 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. Nuclear Decommissioning Trusts The following table shows the fair values and gross unrealized gains and losses for the securities held in the NDT on the Balance Sheet. We provide additional fair value disclosures for the NDT in Note 10.
(1)Maturity dates are 2022-2052. (2)Maturity dates are 2022-2056. (3)Maturity dates are 2022-2072. The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales.
Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities on SDG&E’s Balance Sheet. We determine the cost of securities in the trusts on the basis of specific identification. ASSET RETIREMENT OBLIGATION The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $568 million at December 31, 2021 and is based on a cost study prepared in 2020, which will be submitted to the CPUC in the first half of 2022. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $79 million in 2022, $66 million in 2023, $77 million in 2024, $46 million in 2025, $52 million in 2026, and $718 million thereafter. U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018, which is pending DOE approval. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $4.3 million of retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts. NOTE 13. COMMITMENTS AND CONTINGENCIES LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to reasonably estimate the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued. At December 31, 2021, loss contingency accruals for legal matters that are probable and estimable were $4 million. We discuss our policy regarding accrual of legal fees in Note 1. Ordinary Course Litigation We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases. LEASES A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract. Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate and power generating facilities if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately. Lessee Accounting We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities. Some of our leases include options to extend the lease terms for up to 20 years. Our lease liabilities and ROU assets are based on lease terms that may include such options when it is reasonably certain that we will exercise the option. Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. Certain of our leases contain escalation clauses requiring annual increases in rent ranging from 2% to 3% or based on the Consumer Price Index. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year. Variable lease payments that are based on an index or rate are included in the initial measurement of our lease liability and ROU asset based on the index or rate at lease commencement and are not remeasured because of changes to the index or rate. Rather, changes to the index or rate are treated as variable lease payments and recognized in the period in which the obligation for those payments is incurred. Similarly, PPAs for the purchase of renewable energy require lease payments based on a stated rate per MWh produced by the facilities, and we are required to purchase substantially all the output from the facilities. SDG&E is required to pay additional amounts for capacity charges and actual purchases of energy that exceed the minimum energy commitments. Under these contracts, we do not recognize a lease liability or ROU asset for leases for which there are no fixed lease payments. Rather, these variable lease payments are recognized separately as variable lease costs. SDG&E estimates these variable lease payments to be $297 million in 2022, $296 million in 2023, $297 million in 2024, $296 million in 2025, $290 million in 2026 and $2,779 million thereafter. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record a corresponding ROU asset, initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. We test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets. For our operating leases, we recognize a single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. We recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. Our leases do not contain any material residual value guarantees, restrictions or covenants. Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below.
(1)Reflected as Obligations under Capital Lease – Current for FERC reporting. (2)Reflected as Obligations under Capital Lease – Noncurrent for FERC reporting. The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:
(1)Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts. (2)Substantially all amounts are related to purchased-power contracts. Leases that Have Not Yet Commenced SDG&E has entered into three energy storage tolling agreements, of which it expects two will commence in the third quarter of 2022 and one will commence in the second quarter of 2023. SDG&E expects to account for these agreements as operating leases upon commencement and expects the future minimum lease payments to be $8 million in 2022, $17 million in 2023, $18 million in each of 2024 through 2026 and $101 million thereafter until expiration at various dates from 2032 through 2033. . CONTRACTUAL COMMITMENTS Natural Gas Contracts SoCalGas has responsibility for procuring natural gas for both SDG&E’s and SoCalGas’ core customers in a combined portfolio. SoCalGas buys natural gas under short-term and long-term contracts for this portfolio from various producing regions in the southwestern U.S., U.S. Rockies and Canada. SoCalGas transports natural gas primarily under long-term firm interstate pipeline capacity agreements that provide for annual reservation charges, which are recovered in rates. SoCalGas has commitments with interstate pipeline companies for firm pipeline capacity under contracts that expire at various dates through 2032. Purchased-Power Contracts For 2022, SDG&E expects to meet its customer power requirements from the following resource types: ▪Long-term contracts: 60% (of which 57% is provided by renewable energy contracts expiring on various dates through 2042) ▪Other SDG&E-owned generation and tolling contracts expiring on various dates through 2039: 46% ▪Spot market sales: (6)% Payments on our purchased-power contracts could exceed the minimum commitments based on energy needs. At December 31, 2021, the future minimum payments under long-term purchased-power contracts for SDG&E are as follows:
(1)Excludes purchase agreements accounted for as finance leases. Payments on these contracts represent capacity charges and minimum energy and transmission purchases that exceed the minimum commitment. SDG&E is required to pay additional amounts for actual purchases of energy that exceed the minimum energy commitments. SDG&E estimates these variable payments to be $63 million in each of 2022 through 2026 and $430 million thereafter. Total payments under purchased-power contracts for SDG&E were $495 million in 2021, $534 million in 2020 and $744 million in 2019. Construction and Development Projects At December 31, 2021, SDG&E has commitments to make future payments of $27 million for construction projects that include: ▪$4 million for infrastructure improvements for electric and natural gas transmission and distribution systems; and ▪$23 million related to spent fuel management at SONGS. SDG&E expects future payments under these contractual commitments to be $3 million in each of 2022 and 2023, $1 million in each of 2024 through 2026 and $18 million thereafter. OTHER COMMITMENTS We discuss nuclear insurance and nuclear fuel disposal related to SONGS in Note 12. Fire Mitigation Fund In connection with the completion of the Sunrise Powerlink project in 2012, the CPUC required that SDG&E establish a fire mitigation fund to minimize the risk of fire as well as reduce the potential wildfire impact on residences and structures near the Sunrise Powerlink. The future payments for these contractual commitments, for which a liability has been recorded, are expected to be $4 million per year in 2022 through 2026 and $275 million thereafter, subject to escalation of 2% per year, for a remaining 48-year period. At December 31, 2021, the present value of these future payments of $122 million has been recorded as a regulatory asset as the amounts represent a cost that we expect will be recovered from customers in the future. Franchise Agreements In December 2020, the City of San Diego and SDG&E agreed to extend SDG&E’s natural gas and electric franchises for the city to June 1, 2021. After completing a competitive bid process, on June 8, 2021, the City of San Diego approved ordinances granting to SDG&E the natural gas and electric franchises for the city. These franchise agreements provide SDG&E the opportunity to serve the City of San Diego for the next 20 years, consisting of 10-year agreements that will automatically renew for an additional 10 years unless the City Council voids the automatic renewal with a supermajority vote. The agreements went into effect in July 2021. Over the 20-year term of the agreements, SDG&E will make principal payments of $110 million and interest payments of $13 million as consideration for the natural gas and electric franchise agreements. The consideration paid will not be recovered from customers and will be amortized over 20 years. SDG&E paid $11 million to the City of San Diego in 2021. At December 31, 2021, SDG&E has commitments to make future payments of $14 million per year in 2022 through 2024, $15 million in 2025, $4 million in 2026 and $51 million thereafter. Two lawsuits have been filed in the California Superior Court challenging the City’s process for its award of the natural gas and electric franchises and seeking to declare the franchise agreements null and void. ENVIRONMENTAL ISSUES Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a PRP under the federal Superfund laws and similar state laws. In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Our costs to operate our facilities in compliance with these laws and regulations generally have been recovered in customer rates. We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $14 million at December 31, 2021. Other Environmental Issues We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations:
Our costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates. The environmental issues currently facing us include (1) investigation and remediation of manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by us at which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS. The table below shows the status at December 31, 2021 of our manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:
(1)There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring. We record environmental liabilities when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise engineering evaluations. We review our accruals periodically and, as investigations and cleanups proceed, we make adjustments as necessary. The following table shows our accrued liabilities for environmental matters at December 31, 2021.
(1)Sites for which we have been identified as a PRP. (2)Includes $1 million classified as current liabilities, and $4 million classified as noncurrent liabilities on SDG&E’s Balance Sheet. (3)Does not include SDG&E’s liability for SONGS marine environment mitigation. In connection with the issuance of operating permits, SDG&E and the other owners of SONGS previously reached an agreement with the CCC to mitigate the damage to the marine environment caused by the cooling-water discharge from SONGS during its operation. SONGS’ early retirement, described in Note 12, does not reduce SDG&E’s mitigation obligation. SDG&E’s share of the estimated mitigation costs is $97 million, of which $53 million has been incurred through December 31, 2021 and $44 million is accrued for remaining costs through 2053, which is recoverable in rates and included in noncurrent Regulatory Assets on the Balance Sheet. We expect future payments related to our environmental liabilities on an undiscounted basis to be $2 million in each of 2022 through 2025, $14 million in 2026 and $40 million thereafter. |
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Subsequent Events We evaluated events and transactions that occurred after December 31, 2021 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation. |
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
The following terms and abbreviations appearing in the text of this report have the meanings indicated below.
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES |
||||||||||
|
||||||||||
| Line No. |
Item (a) |
Unrealized Gains and Losses on Available-For-Sale Securities (b) |
Minimum Pension Liability Adjustment (net amount) (c) |
Foreign Currency Hedges (d) |
Other Adjustments (e) |
Other Cash Flow Hedges Interest Rate Swaps (f) |
Other Cash Flow Hedges [Specify] (g) |
Totals for each category of items recorded in Account 219 (h) |
Net Income (Carried Forward from Page 116, Line 78) (i) |
Total Comprehensive Income (j) |
| 1 | Balance of Account 219 at Beginning of Preceding Year |
|||||||||
| 2 | Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income |
|||||||||
| 3 | Preceding Quarter/Year to Date Changes in Fair Value |
|||||||||
| 4 | Total (lines 2 and 3) |
|||||||||
| 5 | Balance of Account 219 at End of Preceding Quarter/Year |
|||||||||
| 6 | Balance of Account 219 at Beginning of Current Year |
|||||||||
| 7 | Current Quarter/Year to Date Reclassifications from Account 219 to Net Income |
|||||||||
| 8 | Current Quarter/Year to Date Changes in Fair Value |
|||||||||
| 9 | Total (lines 7 and 8) |
(a) |
||||||||
| 10 | Balance of Account 219 at End of Current Quarter/Year |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NetIncomeLoss |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION |
||||||||
|
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function. |
||||||||
| Line No. |
Classification (a) |
Total Company For the Current Year/Quarter Ended (b) |
Electric (c) |
Gas (d) |
Other (Specify) (e) |
Other (Specify) (f) |
Other (Specify) (g) |
Common (h) |
|
1 |
UtilityPlantAbstract UTILITY PLANT |
|||||||
|
2 |
UtilityPlantInServiceAbstract In Service |
|||||||
|
3 |
UtilityPlantInServiceClassified Plant in Service (Classified) |
|
|
|
|
|||
|
4 |
UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases |
|
|
|
||||
|
5 |
UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold |
|
||||||
|
6 |
UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified |
|
||||||
|
7 |
UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified |
|
||||||
|
8 |
UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7) |
|
|
|
|
|||
|
9 |
UtilityPlantLeasedToOthers Leased to Others |
|
|
|||||
|
10 |
UtilityPlantHeldForFutureUse Held for Future Use |
|
||||||
|
11 |
ConstructionWorkInProgress Construction Work in Progress |
|
|
|
|
|||
|
12 |
UtilityPlantAcquisitionAdjustment Acquisition Adjustments |
|
|
|||||
|
13 |
UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12) |
|
|
|
|
|||
|
14 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion |
(a) |
|
|
|
|||
|
15 |
UtilityPlantNet Net Utility Plant (13 less 14) |
|
|
|
|
|||
|
16 |
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION |
|||||||
|
17 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service: |
|||||||
|
18 |
DepreciationUtilityPlantInService Depreciation |
|
|
|
|
|||
|
19 |
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights |
|
||||||
|
20 |
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights |
|
||||||
|
21 |
AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant |
|
|
|
|
|||
|
22 |
DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21) |
|
|
|
|
|||
|
23 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others |
|||||||
|
24 |
DepreciationUtilityPlantLeasedToOthers Depreciation |
|
|
|||||
|
25 |
AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion |
|
||||||
|
26 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25) |
|
|
|||||
|
27 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use |
|||||||
|
28 |
DepreciationUtilityPlantHeldForFutureUse Depreciation |
|
||||||
|
29 |
AmortizationUtilityPlantHeldForFutureUse Amortization |
|
||||||
|
30 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29) |
|
||||||
|
31 |
AbandonmentOfLeases Abandonment of Leases (Natural Gas) |
|
||||||
|
32 |
AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment |
|
|
|||||
|
33 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32) |
(b) |
|
|
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reclassification as of 12/2021 Accum. Provision for Depreciation & Amortization for Ratemaking
Accumulated Provision for Depreciation & Amortization Classified
under FERC Seven Factor Test
In Accordance with Guidelines in FERC Order 888
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reclassification as of 12/2021 Accum. Provision for Depreciation & Amortization for Ratemaking
Accumulated Provision for Depreciation & Amortization Classified
under FERC Seven Factor Test
In Accordance with Guidelines in FERC Order 888
| |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157) |
||||||
|
||||||
| Line No. |
Description of item (a) |
Balance Beginning of Year (b) |
Changes during Year Additions (c) |
Changes during Year Amortization (d) |
Changes during Year Other Reductions (Explain in a footnote) (e) |
Balance End of Year (f) |
|
1 |
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1) |
|||||
|
2 |
Fabrication |
|||||
|
3 |
Nuclear Materials |
|||||
|
4 |
Allowance for Funds Used during Construction |
|||||
|
5 |
(Other Overhead Construction Costs, provide details in footnote) |
|||||
|
6 |
SUBTOTAL (Total 2 thru 5) |
|||||
|
7 |
Nuclear Fuel Materials and Assemblies |
|||||
|
8 |
In Stock (120.2) |
|||||
|
9 |
In Reactor (120.3) |
|||||
|
10 |
SUBTOTAL (Total 8 & 9) |
|||||
|
11 |
Spent Nuclear Fuel (120.4) |
|||||
|
12 |
Nuclear Fuel Under Capital Leases (120.6) |
|||||
|
13 |
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5) |
|||||
|
14 |
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13) |
|||||
|
15 |
Estimated Net Salvage Value of Nuclear Materials in Line 9 |
|||||
|
16 |
Estimated Net Salvage Value of Nuclear Materials in Line 11 |
|||||
|
17 |
Est Net Salvage Value of Nuclear Materials in Chemical Processing |
|||||
|
18 |
Nuclear Materials held for Sale (157) |
|||||
|
19 |
Uranium |
|||||
|
20 |
Plutonium |
|||||
|
21 |
Other (Provide details in footnote) |
|||||
|
22 |
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21) |
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106) |
|||||||
|
|||||||
| Line No. |
Account (a) |
Balance Beginning of Year (b) |
Additions (c) |
Retirements (d) |
Adjustments (e) |
Transfers (f) |
Balance at End of Year (g) |
|
1 |
1. INTANGIBLE PLANT |
||||||
|
2 |
(301) Organization |
||||||
|
3 |
(302) Franchise and Consents |
|
|
||||
|
4 |
(303) Miscellaneous Intangible Plant |
|
|
|
|
||
|
5 |
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) |
|
|
|
|
||
|
6 |
2. PRODUCTION PLANT |
||||||
|
7 |
A. Steam Production Plant |
||||||
|
8 |
(310) Land and Land Rights |
|
|
||||
|
9 |
(311) Structures and Improvements |
|
|
|
|
||
|
10 |
(312) Boiler Plant Equipment |
|
|
|
|
||
|
11 |
(313) Engines and Engine-Driven Generators |
||||||
|
12 |
(314) Turbogenerator Units |
|
|
|
|
||
|
13 |
(315) Accessory Electric Equipment |
|
|
|
|||
|
14 |
(316) Misc. Power Plant Equipment |
|
|
|
|
||
|
15 |
(317) Asset Retirement Costs for Steam Production |
|
|
|
|||
|
16 |
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15) |
|
|
|
|
||
|
17 |
B. Nuclear Production Plant |
||||||
|
18 |
(320) Land and Land Rights |
||||||
|
19 |
(321) Structures and Improvements |
||||||
|
20 |
(322) Reactor Plant Equipment |
||||||
|
21 |
(323) Turbogenerator Units |
||||||
|
22 |
(324) Accessory Electric Equipment |
||||||
|
23 |
(325) Misc. Power Plant Equipment |
||||||
|
24 |
(326) Asset Retirement Costs for Nuclear Production |
||||||
|
25 |
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24) |
||||||
|
26 |
C. Hydraulic Production Plant |
||||||
|
27 |
(330) Land and Land Rights |
||||||
|
28 |
(331) Structures and Improvements |
||||||
|
29 |
(332) Reservoirs, Dams, and Waterways |
||||||
|
30 |
(333) Water Wheels, Turbines, and Generators |
||||||
|
31 |
(334) Accessory Electric Equipment |
||||||
|
32 |
(335) Misc. Power Plant Equipment |
||||||
|
33 |
(336) Roads, Railroads, and Bridges |
||||||
|
34 |
(337) Asset Retirement Costs for Hydraulic Production |
||||||
|
35 |
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34) |
||||||
|
36 |
D. Other Production Plant |
||||||
|
37 |
(340) Land and Land Rights |
|
|
||||
|
38 |
(341) Structures and Improvements |
|
|
|
|
|
|
|
39 |
(342) Fuel Holders, Products, and Accessories |
|
|
|
|||
|
40 |
(343) Prime Movers |
|
|
|
|
||
|
41 |
(344) Generators |
|
|
|
|
|
|
|
42 |
(345) Accessory Electric Equipment |
|
|
|
|
||
|
43 |
(346) Misc. Power Plant Equipment |
|
|
|
|
||
|
44 |
(347) Asset Retirement Costs for Other Production |
||||||
|
44.1 |
(348) Energy Storage Equipment - Production |
||||||
|
45 |
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44) |
|
|
|
|
|
|
|
46 |
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45) |
|
|
|
|
|
|
|
47 |
3. Transmission Plant |
||||||
|
48 |
(350) Land and Land Rights |
|
|
|
|
||
|
48.1 |
(351) Energy Storage Equipment - Transmission |
||||||
|
49 |
(352) Structures and Improvements |
|
|
|
|
|
|
|
50 |
(353) Station Equipment |
|
|
|
|
|
|
|
51 |
(354) Towers and Fixtures |
|
|
|
|
||
|
52 |
(355) Poles and Fixtures |
|
|
|
|
|
|
|
53 |
(356) Overhead Conductors and Devices |
|
|
|
|
|
|
|
54 |
(357) Underground Conduit |
|
|
|
|
||
|
55 |
(358) Underground Conductors and Devices |
|
|
|
|
||
|
56 |
(359) Roads and Trails |
|
|
|
|
||
|
57 |
(359.1) Asset Retirement Costs for Transmission Plant |
|
|
|
|||
|
58 |
TOTAL Transmission Plant (Enter Total of lines 48 thru 57) |
|
|
|
|
|
|
|
59 |
4. Distribution Plant |
||||||
|
60 |
(360) Land and Land Rights |
|
|
|
|
|
|
|
61 |
(361) Structures and Improvements |
|
|
|
|
|
|
|
62 |
(362) Station Equipment |
|
|
|
|
|
|
|
63 |
(363) Energy Storage Equipment – Distribution |
|
|
|
|
||
|
64 |
(364) Poles, Towers, and Fixtures |
|
|
|
|
|
|
|
65 |
(365) Overhead Conductors and Devices |
|
|
|
|
|
|
|
66 |
(366) Underground Conduit |
|
|
|
|
|
|
|
67 |
(367) Underground Conductors and Devices |
|
|
|
|
|
|
|
68 |
(368) Line Transformers |
|
|
|
|
|
|
|
69 |
(369) Services |
|
|
|
|
|
|
|
70 |
(370) Meters |
|
|
|
|
|
|
|
71 |
(371) Installations on Customer Premises |
|
|
|
|
|
|
|
72 |
(372) Leased Property on Customer Premises |
||||||
|
73 |
(373) Street Lighting and Signal Systems |
|
|
|
|
|
|
|
74 |
(374) Asset Retirement Costs for Distribution Plant |
|
|
|
|||
|
75 |
TOTAL Distribution Plant (Enter Total of lines 60 thru 74) |
|
|
|
|
|
|
|
76 |
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT |
||||||
|
77 |
(380) Land and Land Rights |
||||||
|
78 |
(381) Structures and Improvements |
||||||
|
79 |
(382) Computer Hardware |
||||||
|
80 |
(383) Computer Software |
||||||
|
81 |
(384) Communication Equipment |
||||||
|
82 |
(385) Miscellaneous Regional Transmission and Market Operation Plant |
||||||
|
83 |
(386) Asset Retirement Costs for Regional Transmission and Market Oper |
||||||
|
84 |
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83) |
||||||
|
85 |
6. General Plant |
||||||
|
86 |
(389) Land and Land Rights |
|
|
||||
|
87 |
(390) Structures and Improvements |
|
|
|
|
||
|
88 |
(391) Office Furniture and Equipment |
||||||
|
89 |
(392) Transportation Equipment |
|
|
||||
|
90 |
(393) Stores Equipment |
|
|
|
|||
|
91 |
(394) Tools, Shop and Garage Equipment |
|
|
|
|
|
|
|
92 |
(395) Laboratory Equipment |
|
|
||||
|
93 |
(396) Power Operated Equipment |
|
|
||||
|
94 |
(397) Communication Equipment |
|
|
|
|
|
|
|
95 |
(398) Miscellaneous Equipment |
|
|
|
|
|
|
|
96 |
SUBTOTAL (Enter Total of lines 86 thru 95) |
|
|
|
|
|
|
|
97 |
(399) Other Tangible Property |
||||||
|
98 |
(399.1) Asset Retirement Costs for General Plant |
||||||
|
99 |
TOTAL General Plant (Enter Total of lines 96, 97, and 98) |
|
|
|
|
|
|
|
100 |
TOTAL (Accounts 101 and 106) |
|
|
|
|
|
|
|
101 |
(102) Electric Plant Purchased (See Instr. 8) |
||||||
|
102 |
(Less) (102) Electric Plant Sold (See Instr. 8) |
||||||
|
103 |
(103) Experimental Plant Unclassified |
||||||
|
104 |
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103) |
|
|
|
|
|
(a) |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: ElectricPlantInService | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reclassification of 2021 Electric Plant-in-Service for Ratemaking
Plant in Service Classified under FERC Seven Factor Test
In Accordance with Guidelines in FERC Order 888
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC PLANT LEASED TO OTHERS (Account 104) |
||||||
| Line No. |
LesseeName Name of Lessee (a) |
IndicationOfAssociatedCompany * (Designation of Associated Company) (b) |
LeaseDescription Description of Property Leased (c) |
CommissionAuthorization Commission Authorization (d) |
ExpirationDateOfLease Expiration Date of Lease (e) |
ElectricPlantLeasedToOthers Balance at End of Year (f) |
| 1 | True |
|||||
| 2 | ||||||
| 3 | True |
|||||
| 4 | ||||||
| 47 |
TOTAL |
|
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105) |
|||||||||
|
|||||||||
| Line No. |
ElectricPlantHeldForFutureUseDescription Description and Location of Property (a) |
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b) |
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c) |
ElectricPlantHeldForFutureUse Balance at End of Year (d) |
|||||
| 1 | Land and Rights: | ||||||||
| 2 | |||||||||
| 3 | |||||||||
| 4 | |||||||||
| 5 | |||||||||
| 6 | |||||||||
| 7 | |||||||||
| 8 | |||||||||
| 9 | |||||||||
| 10 | |||||||||
| 11 | |||||||||
| 12 | |||||||||
| 13 | |||||||||
| 14 | |||||||||
| 15 | |||||||||
| 16 | |||||||||
| 17 | |||||||||
| 18 | |||||||||
| 19 | |||||||||
| 20 | |||||||||
| 21 | Other Property: | ||||||||
| 22 | |||||||||
| 23 | |||||||||
| 24 | |||||||||
| 25 | |||||||||
| 26 | |||||||||
| 27 | |||||||||
| 28 | |||||||||
| 29 | |||||||||
| 30 | |||||||||
| 31 | |||||||||
| 32 | |||||||||
| 33 | |||||||||
| 34 | |||||||||
| 35 | |||||||||
| 36 | |||||||||
| 37 | |||||||||
| 38 | |||||||||
| 39 | |||||||||
| 40 | |||||||||
| 41 | |||||||||
| 42 | |||||||||
| 43 | |||||||||
| 44 | |||||||||
| 45 | |||||||||
| 46 | |||||||||
| 47 | TOTAL | ||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107) |
||
|
||
| Line No. |
ConstructionWorkInProgressProjectDescription Description of Project (a) |
ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b) |
| 1 | ||
| 2 | ||
| 3 | ||
| 4 | ||
| 5 | ||
| 6 | ||
| 7 | ||
| 8 | ||
| 9 | ||
| 10 | ||
| 11 | ||
| 12 | ||
| 13 | ||
| 14 | ||
| 15 | ||
| 16 | ||
| 17 | ||
| 18 | ||
| 19 | ||
| 20 | ||
| 21 | ||
| 22 | ||
| 23 | ||
| 24 | ||
| 25 | ||
| 26 | ||
| 27 | ||
| 28 | ||
| 29 | ||
| 30 | ||
| 31 | ||
| 32 | ||
| 33 | ||
| 34 | ||
| 35 | ||
| 36 | ||
| 37 | ||
| 38 | ||
| 39 | ||
| 40 | ||
| 41 | ||
| 42 | ||
| 43 | ||
| 44 | ||
| 45 | ||
| 46 | ||
| 47 | ||
| 48 | ||
| 49 | ||
| 50 | ||
| 51 | ||
| 52 | ||
| 53 | ||
| 54 | ||
| 55 | ||
| 56 | ||
| 57 | ||
| 58 | ||
| 59 | ||
| 60 | ||
| 61 | ||
| 62 | ||
| 63 | ||
| 64 | ||
| 65 | ||
| 66 | ||
| 67 | ||
| 68 | ||
| 69 | ||
| 70 | ||
| 71 | ||
| 72 | ||
| 73 | ||
| 74 | ||
| 75 | ||
| 76 | ||
| 77 | ||
| 78 | ||
| 79 | ||
| 80 | ||
| 81 | ||
| 82 | ||
| 83 | ||
| 84 | ||
| 85 | ||
| 86 | ||
| 87 | ||
| 88 | ||
| 89 | ||
| 90 | ||
| 91 | ||
| 92 | ||
| 93 | ||
| 94 | ||
| 95 | ||
| 96 | ||
| 97 | ||
| 98 | ||
| 99 | ||
| 100 | ||
| 101 | ||
| 102 | ||
| 103 | ||
| 104 | ||
| 105 | ||
| 106 | ||
| 107 | ||
| 108 | ||
| 109 | ||
| 110 | ||
| 111 | ||
| 112 | ||
| 113 | ||
| 114 | ||
| 115 | ||
| 116 | ||
| 117 | ||
| 118 | ||
| 119 | ||
| 43 | Total |
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108) |
|||||
|
|||||
| Line No. |
Item (a) |
Total (c + d + e) (b) |
Electric Plant in Service (c) |
Electric Plant Held for Future Use (d) |
Electric Plant Leased To Others (e) |
| Section A. Balances and Changes During Year | |||||
| 1 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year |
|
|
|
|
| 2 |
Depreciation Provisions for Year, Charged to |
||||
|
3 |
DepreciationExpenseExcludingAdjustments (403) Depreciation Expense |
|
(a) |
||
|
4 |
DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs |
||||
|
5 |
ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others |
|
|
||
|
6 |
TransportationExpensesClearing Transportation Expenses-Clearing |
||||
|
7 |
OtherClearingAccounts Other Clearing Accounts |
||||
|
8 |
OtherAccounts Other Accounts (Specify, details in footnote): |
||||
| 9.1 | |||||
| 10 |
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9) |
|
|
|
|
| 11 |
Net Charges for Plant Retired: |
||||
|
12 |
BookCostOfRetiredPlant Book Cost of Plant Retired |
|
(b) |
||
|
13 |
CostOfRemovalOfPlant Cost of Removal |
|
|
||
|
14 |
SalvageValueOfRetiredPlant Salvage (Credit) |
|
|
||
|
15 |
NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14) |
|
|
||
| 16 |
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote): |
||||
| 17.1 | (c) |
||||
| 18 |
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired |
|
|
||
| 19 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18) |
|
|
|
|
| Section B. Balances at End of Year According to Functional Classification | |||||
|
20 |
AccumulatedDepreciationSteamProduction Steam Production |
|
|
||
|
21 |
AccumulatedDepreciationNuclearProduction Nuclear Production |
||||
|
22 |
AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional |
||||
|
23 |
AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage |
||||
|
24 |
AccumulatedDepreciationOtherProduction Other Production |
|
|
||
|
25 |
AccumulatedDepreciationTransmission Transmission |
|
|
|
|
|
26 |
AccumulatedDepreciationDistribution Distribution |
|
|
||
|
27 |
AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation |
||||
|
28 |
AccumulatedDepreciationGeneral General |
|
|
||
| 29 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28) |
|
|
|
|
| FOOTNOTE DATA |
| (a) Concept: DepreciationExpenseExcludingAdjustments | ||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||
| (b) Concept: BookCostOfRetiredPlant | ||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||
| (c) Concept: OtherAdjustmentsToAccumulatedDepreciation | ||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) |
||||||||
|
||||||||
| Line No. |
DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a) |
DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b) |
DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c) |
InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d) |
EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e) |
InterestAndDividendRevenueFromInvestments Revenues for Year (f) |
InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g) |
InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h) |
| 1 | ||||||||
| 2 | ||||||||
| 3 | ||||||||
| 4 | ||||||||
| 5 | ||||||||
| 6 | ||||||||
| 7 | ||||||||
| 8 | ||||||||
| 9 | ||||||||
| 10 | ||||||||
| 11 | ||||||||
| 12 | ||||||||
| 13 | ||||||||
| 14 | ||||||||
| 15 | ||||||||
| 16 | ||||||||
| 17 | ||||||||
| 18 | ||||||||
| 19 | ||||||||
| 20 | ||||||||
| 21 | ||||||||
| 22 | ||||||||
| 23 | ||||||||
| 24 | ||||||||
| 25 | ||||||||
| 26 | ||||||||
| 27 | ||||||||
| 28 | ||||||||
| 29 | ||||||||
| 30 | ||||||||
| 31 | ||||||||
| 32 | ||||||||
| 33 | ||||||||
| 34 | ||||||||
| 35 | ||||||||
| 36 | ||||||||
| 37 | ||||||||
| 38 | ||||||||
| 39 | ||||||||
| 40 | ||||||||
| 41 | ||||||||
| 42 |
Total Cost of Account 123.1 $ |
Total | ||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MATERIALS AND SUPPLIES |
||||
|
||||
| Line No. |
Account (a) |
Balance Beginning of Year (b) |
Balance End of Year (c) |
Department or Departments which Use Material (d) |
| 1 |
Fuel Stock (Account 151) |
|||
| 2 |
Fuel Stock Expenses Undistributed (Account 152) |
|||
| 3 |
Residuals and Extracted Products (Account 153) |
|||
| 4 |
Plant Materials and Operating Supplies (Account 154) |
|||
| 5 |
Assigned to - Construction (Estimated) |
|
|
|
| 6 |
Assigned to - Operations and Maintenance |
|||
| 7 |
Production Plant (Estimated) |
|||
| 8 |
Transmission Plant (Estimated) |
|||
| 9 |
Distribution Plant (Estimated) |
|||
| 10 |
Regional Transmission and Market Operation Plant (Estimated) |
|||
| 11 |
Assigned to - Other (provide details in footnote) |
|
|
|
| 12 |
TOTAL Account 154 (Enter Total of lines 5 thru 11) |
|
|
|
| 13 |
Merchandise (Account 155) |
|||
| 14 |
Other Materials and Supplies (Account 156) |
|
||
| 15 |
Nuclear Materials Held for Sale (Account 157) (Not
applic to Gas Util) |
|||
| 16 |
Stores Expense Undistributed (Account 163) |
|
||
| 17 | ||||
| 18 | ||||
| 19 | ||||
| 20 |
TOTAL Materials and Supplies |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| Current Year | Year One | Year Two | Year Three | Future Years | Totals | ||||||||
| Line No. |
SO2 Allowances Inventory (Account 158.1) (a) |
No. (b) |
Amt. (c) |
No. (d) |
Amt. (e) |
No. (f) |
Amt. (g) |
No. (h) |
Amt. (i) |
No. (j) |
Amt. (k) |
No. (l) |
Amt. (m) |
1 |
Balance-Beginning of Year |
||||||||||||
2 |
|||||||||||||
3 |
Acquired During Year: |
||||||||||||
4 |
Issued (Less Withheld Allow) |
||||||||||||
5 |
Returned by EPA |
||||||||||||
6 |
|||||||||||||
7 |
|||||||||||||
8 |
|||||||||||||
9 |
|||||||||||||
10 |
|||||||||||||
11 |
|||||||||||||
12 |
|||||||||||||
13 |
|||||||||||||
14 |
|||||||||||||
15 |
Total |
||||||||||||
16 |
|||||||||||||
17 |
Relinquished During Year: |
||||||||||||
18 |
Charges to Account 509 |
||||||||||||
19 |
Other: |
||||||||||||
20 |
Allowances Used |
||||||||||||
21 |
Cost of Sales/Transfers: |
||||||||||||
22 |
|||||||||||||
23 |
|||||||||||||
24 |
|||||||||||||
25 |
|||||||||||||
26 |
|||||||||||||
27 |
|||||||||||||
28 |
Total |
||||||||||||
29 |
Balance-End of Year |
||||||||||||
30 |
|||||||||||||
31 |
Sales: |
||||||||||||
32 |
Net Sales Proceeds(Assoc. Co.) |
||||||||||||
33 |
Net Sales Proceeds (Other) |
||||||||||||
34 |
Gains |
||||||||||||
35 |
Losses |
||||||||||||
Allowances Withheld (Acct 158.2) |
|||||||||||||
36 |
Balance-Beginning of Year |
||||||||||||
37 |
Add: Withheld by EPA |
||||||||||||
38 |
Deduct: Returned by EPA |
||||||||||||
39 |
Cost of Sales |
||||||||||||
40 |
Balance-End of Year |
||||||||||||
41 |
|||||||||||||
42 |
Sales |
||||||||||||
43 |
Net Sales Proceeds (Assoc. Co.) |
||||||||||||
44 |
Net Sales Proceeds (Other) |
||||||||||||
45 |
Gains |
||||||||||||
46 |
Losses |
||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| Current Year | Year One | Year Two | Year Three | Future Years | Totals | ||||||||
| Line No. |
NOx Allowances Inventory (Account 158.1) (a) |
No. (b) |
Amt. (c) |
No. (d) |
Amt. (e) |
No. (f) |
Amt. (g) |
No. (h) |
Amt. (i) |
No. (j) |
Amt. (k) |
No. (l) |
Amt. (m) |
1 |
Balance-Beginning of Year |
||||||||||||
2 |
|||||||||||||
3 |
Acquired During Year: |
||||||||||||
4 |
Issued (Less Withheld Allow) |
||||||||||||
5 |
Returned by EPA |
||||||||||||
6 |
|||||||||||||
7 |
|||||||||||||
8 |
|||||||||||||
9 |
|||||||||||||
10 |
|||||||||||||
11 |
|||||||||||||
12 |
|||||||||||||
13 |
|||||||||||||
14 |
|||||||||||||
15 |
Total |
||||||||||||
16 |
|||||||||||||
17 |
Relinquished During Year: |
||||||||||||
18 |
Charges to Account 509 |
||||||||||||
19 |
Other: |
||||||||||||
20 |
Allowances Used |
||||||||||||
21 |
Cost of Sales/Transfers: |
||||||||||||
22 |
|||||||||||||
23 |
|||||||||||||
24 |
|||||||||||||
25 |
|||||||||||||
26 |
|||||||||||||
27 |
|||||||||||||
28 |
Total |
||||||||||||
29 |
Balance-End of Year |
||||||||||||
30 |
|||||||||||||
31 |
Sales: |
||||||||||||
32 |
Net Sales Proceeds(Assoc. Co.) |
||||||||||||
33 |
Net Sales Proceeds (Other) |
||||||||||||
34 |
Gains |
||||||||||||
35 |
Losses |
||||||||||||
Allowances Withheld (Acct 158.2) |
|||||||||||||
36 |
Balance-Beginning of Year |
||||||||||||
37 |
Add: Withheld by EPA |
||||||||||||
38 |
Deduct: Returned by EPA |
||||||||||||
39 |
Cost of Sales |
||||||||||||
40 |
Balance-End of Year |
||||||||||||
41 |
|||||||||||||
42 |
Sales |
||||||||||||
43 |
Net Sales Proceeds (Assoc. Co.) |
||||||||||||
44 |
Net Sales Proceeds (Other) |
||||||||||||
45 |
Gains |
||||||||||||
46 |
Losses |
||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
EXTRAORDINARY PROPERTY LOSSES (Account 182.1) |
||||||
| WRITTEN OFF DURING YEAR | ||||||
| Line No. |
DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a) |
ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b) |
ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c) |
ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d) |
ExtraordinaryPropertyLossesWrittenOff Amount (e) |
ExtraordinaryPropertyLosses Balance at End of Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 20 | TOTAL | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2) |
||||||
| WRITTEN OFF DURING YEAR | ||||||
| Line No. |
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a) |
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b) |
UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c) |
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d) |
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e) |
UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f) |
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 29 | ||||||
| 30 | ||||||
| 31 | ||||||
| 32 | ||||||
| 33 | ||||||
| 34 | ||||||
| 35 | ||||||
| 36 | ||||||
| 37 | ||||||
| 38 | ||||||
| 39 | ||||||
| 40 | ||||||
| 41 | ||||||
| 42 | ||||||
| 43 | ||||||
| 44 | ||||||
| 45 | ||||||
| 46 | ||||||
| 47 | ||||||
| 48 | ||||||
| 49 |
TOTAL |
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Transmission Service and Generation Interconnection Study Costs |
|||||
|
|||||
| Line No. |
DescriptionOfStudyPerformed Description (a) |
StudyCostsIncurred Costs Incurred During Period (b) |
StudyCostsAccountCharged Account Charged (c) |
StudyCostsReimbursements Reimbursements Received During the Period (d) |
StudyCostsAccountReimbursed Account Credited With Reimbursement (e) |
| 1 |
Transmission Studies |
||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 |
Total |
||||
| 21 |
Generation Studies |
||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 |
Total |
||||
| 40 | Grand Total | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY ASSETS (Account 182.3) |
||||||
|
||||||
| CREDITS | ||||||
| Line No. |
DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a) |
OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b) |
IncreaseDecreaseInOtherRegulatoryAssets Debits (c) |
OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d) |
OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e) |
OtherRegulatoryAssets Balance at end of Current Quarter/Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 44 |
TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MISCELLANEOUS DEFFERED DEBITS (Account 186) |
||||||
|
||||||
| CREDITS | ||||||
| Line No. |
Description of Miscellaneous Deferred Debits (a) |
Balance at Beginning of Year (b) |
Debits (c) |
Credits Account Charged (d) |
Credits Amount (e) |
Balance at End of Year (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|||||
| 4 |
|
|||||
| 5 |
|
|
|
|
|
|
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
||
| 9 |
|
|
|
|||
| 10 |
|
|
|
|||
| 11 |
|
|
|
|
||
| 12 |
|
|
|
|
|
|
| 13 |
|
|
|
|
||
| 14 |
|
|
|
|||
| 15 |
|
|
|
|
|
|
| 16 |
|
|||||
| 17 |
|
|
|
|
|
|
| 18 |
|
|
|
|||
| 19 |
|
|
|
|
|
|
| 20 |
|
|
|
|||
| 47 |
Miscellaneous Work in Progress |
|||||
| 48 |
Deferred Regulatroy Comm. Expenses (See pages 350 - 351) |
|||||
| 49 |
TOTAL |
|
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES (Account 190) |
|||
|
|||
| Line No. |
DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a) |
AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b) |
AccumulatedDeferredIncomeTaxes Balance at End of Year (c) |
| 1 |
Electric |
||
| 2 |
|
(a) |
(b) |
| 3 |
|
|
|
| 7 |
Other |
||
| 8 |
TOTAL Electric (Enter Total of lines 2 thru 7) |
(c) |
(d) |
| 9 |
Gas |
||
| 10 |
|
|
|
| 11 |
|
|
|
| 15 |
Other |
||
| 16 |
TOTAL Gas (Enter Total of lines 10 thru 15) |
|
|
|
17.1 |
|
|
|
| 17 |
Other (Specify) |
||
| 18 |
TOTAL (Acct 190) (Total of lines 8, 16 and 17) |
|
|
| Notes |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Account 190 electric balance at the end of the year reflects amortization of transmission related excess deferred federal income taxes in the amount of $1,839,074.
The deferred tax asset related to FERC transmission on a stand-alone basis as of December 31, 2021, 2020, 2019, 2018 and 2017 is reflected in the table below:
STAND-ALONE FERC TRANSMISSION NET OPERATING LOSS DEFERRED TAX ASSET
(1)
(Dollars in millions)
(1) Does not include any amounts related to Citizens.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Account 190 non-Citizen transmission related deferred tax (asset) included in electric accumulated deferred income taxes at the beginning of the year was ($164,013,239).
Account 190 Citizen transmission related deferred tax (asset) included in electric accumulated deferred income taxes at the beginning of the year was ($8,452,524).
Account 190 transmission allocation related other deferred tax (asset) included in electric accumulated deferred income taxes at the beginning of the year was ($2,255,357).
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: AccumulatedDeferredIncomeTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Account 190 non-Citizen transmission related deferred tax (asset) included in electric accumulated deferred income taxes at the end of the year was ($143,286,173).
Account 190 Citizen transmission related deferred tax (asset) included in electric accumulated deferred income taxes at the end of the year was ($7,384,342).
Account 190 transmission allocation related other deferred tax (asset) included in electric accumulated deferred income taxes at the end of the year was ($1,937,052).
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCKS (Account 201 and 204) |
||||||||||
|
||||||||||
| Line No. |
Class and Series of Stock and Name of Stock Series (a) |
Number of Shares Authorized by Charter (b) |
Par or Stated Value per Share (c) |
Call Price at End of Year (d) |
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e) |
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f) |
Held by Respondent As Reacquired Stock (Acct 217) Shares (g) |
Held by Respondent As Reacquired Stock (Acct 217) Cost (h) |
Held by Respondent In Sinking and Other Funds Shares (i) |
Held by Respondent In Sinking and Other Funds Amount (j) |
| 1 |
Common Stock (Account 201) |
|||||||||
| 2 |
|
|
|
|
|
|||||
|
7 |
Total |
|
|
|
||||||
|
8 |
Preferred Stock (Account 204) |
|||||||||
| 9 |
|
|
||||||||
|
11 |
Total |
|
||||||||
| 1 |
Capital Stock (Accounts 201 and 204) - Data Conversion |
|||||||||
| 2 | ||||||||||
| 3 | ||||||||||
| 4 | ||||||||||
|
5 |
Total |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Other Paid-in Capital |
||||||||||||
|
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
|
||||||||||||
| Line No. |
Item (a) |
Amount (b) |
||||||||||
|
1 |
DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208) |
|||||||||||
|
2 |
DonationsReceivedFromStockholders Beginning Balance Amount |
|||||||||||
|
3.1 |
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders |
|||||||||||
|
4 |
DonationsReceivedFromStockholders Ending Balance Amount |
|||||||||||
|
5 |
ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209) |
|||||||||||
|
6 |
ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount |
|||||||||||
|
7.1 |
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock |
|||||||||||
|
8 |
ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount |
|||||||||||
|
9 |
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) |
|||||||||||
|
10 |
GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount |
|||||||||||
|
11.1 |
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock |
|||||||||||
|
12 |
GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount |
|||||||||||
|
13 |
MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211) |
|||||||||||
|
14 |
MiscellaneousPaidInCapital Beginning Balance Amount |
|
||||||||||
|
15.1 |
IncreasesDecreasesDueToMiscellaneousPaidInCapital |
|||||||||||
|
16 |
MiscellaneousPaidInCapital Ending Balance Amount |
|
||||||||||
|
17 |
OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital |
|||||||||||
|
18 |
OtherPaidInCapitalDetail Beginning Balance Amount |
|||||||||||
|
19.1 |
IncreasesDecreasesInOtherPaidInCapital |
|||||||||||
|
20 |
OtherPaidInCapitalDetail Ending Balance Amount |
|||||||||||
|
40 |
OtherPaidInCapital Total |
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCK EXPENSE (Account 214) |
||
|
||
| Line No. |
NameOfClassAndSeriesOfStock Class and Series of Stock (a) |
CapitalStockExpense Balance at End of Year (b) |
| 1 | ||
| 22 |
TOTAL |
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
LONG-TERM DEBT (Account 221, 222, 223 and 224) |
|||||||||||||
|
|||||||||||||
| Line No. |
ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a) |
RelatedAccountNumber Related Account Number (b) |
Principal Amount of Debt Issued (c) |
LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d) |
LongTermDebtIssuanceExpenses Total Expense (e) |
LongTermDebtPremium Total Premium (f) |
LongTermDebtDiscount Total Discount (g) |
NominalDateOfIssue Nominal Date of Issue (h) |
DateOfMaturity Date of Maturity (i) |
AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j) |
AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k) |
Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l) |
Interest for Year Amount (m) |
| 1 |
Bonds (Account 221) |
||||||||||||
| 2 | |||||||||||||
| 3 | |||||||||||||
| 4 | |||||||||||||
| 5 | |||||||||||||
| 6 | |||||||||||||
| 7 | |||||||||||||
| 8 | |||||||||||||
| 9 | |||||||||||||
| 10 | |||||||||||||
| 11 | |||||||||||||
| 12 | |||||||||||||
| 13 | |||||||||||||
| 14 | |||||||||||||
| 15 | |||||||||||||
| 16 | |||||||||||||
| 17 | |||||||||||||
| 18 | |||||||||||||
| 19 | |||||||||||||
|
20 |
Subtotal |
(a) |
(b) |
|
|
|
|||||||
21 |
Reacquired Bonds (Account 222) |
||||||||||||
| 22 | |||||||||||||
| 23 | |||||||||||||
| 24 | |||||||||||||
|
25 |
Subtotal | ||||||||||||
26 |
Advances from Associated Companies (Account 223) |
||||||||||||
| 27 | |||||||||||||
| 28 | |||||||||||||
| 29 | |||||||||||||
|
30 |
Subtotal | ||||||||||||
31 |
Other Long Term Debt (Account 224) |
||||||||||||
| 32 | |||||||||||||
| 33 | |||||||||||||
| 34 | |||||||||||||
|
35 |
Subtotal | ||||||||||||
| 33 | TOTAL |
|
|
|
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: BondsPrincipalAmountIssued | ||||||||||||||||||||||||
D.93-09-069 - At December 2021 total remaining authority for new preferred debt under this decision was $48,360,000.
D.04-01-009 - At December 2021 total remaining authority for new preferred debt under this decision was $4,000,000 and $76,000,000 for rollover preferred.
D.06-05-015 - At December 2021 total remaining authority for new preferred debt under this decision was $200,000,000.
D.08-07-029 - In July 2008, SDG&E received authority from the California Public Utilities Commission to issue $687,000,000 of new debt and $413,000,000 in rollover debt. In August 2021, SDG&E issued 2.9500% First Mortgage bond series WWW for $123,130,000 due 2051. At December 2021 there was no remaining authority.
D.10-10-023 - At December 2021 total remaining authority for new preferred debt under this decision was $150,000,000.
D.18-02-012 - In February 2018, SDG&E received authority from the California Public Utilities Commission to issue $750,000,000 of new debt and $300,000,000 in rollover debt. In August 2021, SDG&E issued 2.9500% First Mortgage bond series WWW for $226,870,000 due 2051. At December 2021 total remaining authority for rollover debt under this decision was $73,130,000.
D.20-04-015 - In April 2020, SDG&E received authority from the California Public Utilities Commission to issue $2,300,000,000 of new debt and $730,000,000 in rollover debt. In August 2021, SDG&E issued 2.9500% First Mortgage bond series WWW for $400,000,000 due 2051. At December 2021 total remaining authority under this decision was $1,115,430,000 for new debt, $803,130,000 for rollover debt, $402,360,000 for new preferred and $76,000,000 for rollover referred.
| ||||||||||||||||||||||||
| (b) Concept: BondIssuanceExpense | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES |
||
|
||
| Line No. |
Particulars (Details) (a) |
Amount (b) |
| 1 |
Net Income for the Year (Page 117) |
(a) |
| 2 |
Reconciling Items for the Year |
|
| 3 | ||
| 4 |
Taxable Income Not Reported on Books |
|
| 5 | ||
| 6 | (b) |
|
| 9 |
Deductions Recorded on Books Not Deducted for Return |
|
| 10 | ||
| 11 | ||
| 12 | ||
| 13 | (c) |
|
| 14 |
Income Recorded on Books Not Included in Return |
|
| 15 | ||
| 16 | ||
| 17 | ||
| 18 | (d) |
|
| 19 |
Deductions on Return Not Charged Against Book Income |
|
| 20 | ||
| 21 | ||
| 22 | ||
| 23 | ||
| 24 | ||
| 25 | ||
| 26 | (e) |
|
| 27 |
Federal Tax Net Income |
|
| 28 |
Show Computation of Tax: |
|
| 29 | ||
| 30 | ||
| 31 | ||
| 32 | ||
| 33 | ||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NetIncomeLoss | ||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: TaxableIncomeNotReportedOnBooks | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: DeductionsRecordedOnBooksNotDeductedForReturn | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: IncomeRecordedOnBooksNotIncludedInReturn | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: DeductionsOnReturnNotChargedAgainstBookIncome | ||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR |
|||||||||||||||
|
|||||||||||||||
| BALANCE AT BEGINNING OF YEAR | BALANCE AT END OF YEAR | DISTRIBUTION OF TAXES CHARGED | |||||||||||||
| Line No. |
DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a) |
TypeOfTax Type of Tax (b) |
TaxJurisdiction State (c) |
TaxYear Tax Year (d) |
TaxesAccrued Taxes Accrued (Account 236) (e) |
PrepaidTaxes Prepaid Taxes (Include in Account 165) (f) |
TaxesCharged Taxes Charged During Year (g) |
TaxesPaid Taxes Paid During Year (h) |
TaxAdjustments Adjustments (i) |
TaxesAccrued Taxes Accrued (Account 236) (j) |
PrepaidTaxes Prepaid Taxes (Included in Account 165) (k) |
TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l) |
IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m) |
AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n) |
TaxesIncurredOther Other (o) |
| 1 | (a) |
||||||||||||||
| 2 | (e) |
(g) |
|||||||||||||
| 3 | |||||||||||||||
| 4 | |||||||||||||||
| 5 | |||||||||||||||
| 6 | Subtotal Federal Tax |
(b) |
(d) |
(f) |
|||||||||||
| 7 | (c) |
||||||||||||||
| 8 | |||||||||||||||
| 9 | |||||||||||||||
| 10 | |||||||||||||||
| 11 | Subtotal State Tax |
||||||||||||||
| 12 | |||||||||||||||
| 13 | |||||||||||||||
| 14 | |||||||||||||||
| 15 | Subtotal Local Tax |
||||||||||||||
| 16 | |||||||||||||||
| 17 | Subtotal Other Tax |
||||||||||||||
| 18 | Subtotal Property Tax |
||||||||||||||
| 19 | Subtotal Real Estate Tax |
||||||||||||||
| 20 | Subtotal Unemployment Tax |
||||||||||||||
| 21 | Subtotal Sales And Use Tax |
||||||||||||||
| 22 | Subtotal Income Tax |
||||||||||||||
| 23 | Subtotal Excise Tax |
||||||||||||||
| 24 | Subtotal Fuel Tax |
||||||||||||||
| 25 | Subtotal Federal Insurance Tax |
||||||||||||||
| 26 | Subtotal Franchise Tax |
||||||||||||||
| 27 | Subtotal Miscellaneous Other Tax |
||||||||||||||
| 28 | Subtotal Other Federal Tax |
||||||||||||||
| 29 | Subtotal Other State Tax |
||||||||||||||
| 30 | Subtotal Other Property Tax |
||||||||||||||
| 31 | Subtotal Other Use Tax |
||||||||||||||
| 32 | Subtotal Other Advalorem Tax |
||||||||||||||
| 33 | Subtotal Other License And Fees Tax |
||||||||||||||
| 34 | Subtotal Payroll Tax |
||||||||||||||
| 35 | Subtotal Advalorem Tax |
||||||||||||||
| 36 | Subtotal Other Allocated Tax |
||||||||||||||
| 37 | Subtotal Severance Tax |
||||||||||||||
| 38 | Subtotal Penalty Tax |
||||||||||||||
| 39 | Subtotal Other Taxes And Fees |
||||||||||||||
| 40 |
TOTAL |
(h) |
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PrepaidTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: PrepaidTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: PrepaidTaxes | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: TaxAdjustments | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: TaxesAccruedPrepaidAndCharged | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (f) Concept: TaxesAccruedPrepaidAndCharged | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (g) Concept: TaxesIncurredOther | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (h) Concept: TaxesAccrued | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Note 1:
Ad Valorem taxes are allocated based on type of assets in each taxing jurisdiction.
Note 2:
Sales and Use taxes are allocated based on the Common Allocation Factor.
Sales and Use tax adjustments in column "f" are to adjust carry forward balances from last year.
Note 3:
State and Franchise Tax and Federal Income Tax are charged to departments based on total taxable income generated by each department.
Note 4:
Retirement, Unemployment, and Medicare taxes are charged to departments as a percentage of total taxable labor charged.
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) |
|||||||||||
|
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized. |
|||||||||||
| Deferred for Year | Allocations to Current Year's Income | ||||||||||
| Line No. |
Account Subdivisions (a) |
Balance at Beginning of Year (b) |
Account No. (c) |
Amount (d) |
Account No. (e) |
Amount (f) |
Adjustments (g) |
Balance at End of Year (h) |
Average Period of Allocation to Income (i) |
ADJUSTMENT EXPLANATION (j) |
|
| 1 | Electric Utility |
||||||||||
| 2 |
|
||||||||||
| 3 |
|
||||||||||
| 4 |
|
||||||||||
| 5 |
|
||||||||||
| 6 |
|
||||||||||
| 8 |
TOTAL Electric (Enter Total of lines 2 thru 7) |
|
(a) |
|
|||||||
| 9 | Other (List separately and show 3%, 4%, 7%, 10% and TOTAL) |
||||||||||
| 10 | |||||||||||
| 11 | |||||||||||
| 47 | OTHER TOTAL | ||||||||||
| 48 | GRAND TOTAL |
|
|
||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredInvestmentTaxCreditsAllocationToIncomeAmount |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER DEFERRED CREDITS (Account 253) |
||||||
|
||||||
| DEBITS | ||||||
| Line No. |
Description and Other Deferred Credits (a) |
Balance at Beginning of Year (b) |
Contra Account (c) |
Amount (d) |
Credits (e) |
Balance at End of Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 47 |
TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281) |
||||||||||||
|
||||||||||||
| CHANGES DURING YEAR | ADJUSTMENTS | |||||||||||
| Debits | Credits | |||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
|
1 |
Accelerated Amortization (Account 281) |
|||||||||||
2 |
Electric |
|||||||||||
3 |
Defense Facilities |
|||||||||||
4 |
Pollution Control Facilities |
|||||||||||
5 |
Other |
|||||||||||
5.1 |
|
|||||||||||
8 |
TOTAL Electric (Enter Total of lines 3 thru 7) |
|||||||||||
9 |
Gas |
|||||||||||
10 |
Defense Facilities |
|||||||||||
11 |
Pollution Control Facilities |
|||||||||||
12 |
Other |
|||||||||||
12.1 |
|
|||||||||||
15 |
TOTAL Gas (Enter Total of lines 10 thru 14) |
|||||||||||
16 |
Other |
|||||||||||
16.1 |
Other |
|||||||||||
16.2 |
Other |
|||||||||||
17 |
TOTAL (Acct 281) (Total of 8, 15 and 16) |
|||||||||||
| 18 |
Classification of TOTAL |
|||||||||||
| 19 |
Federal Income Tax |
|||||||||||
| 20 |
State Income Tax |
|||||||||||
| 21 |
Local Income Tax |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282) |
||||||||||||
|
||||||||||||
| CHANGES DURING YEAR | ADJUSTMENTS | |||||||||||
| Debits | Credits | |||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
|
| 1 | Account 282 | |||||||||||
2 |
Electric |
(a) |
||||||||||
3 |
Gas |
(b) |
||||||||||
4 |
Other (Specify) |
|||||||||||
5 |
Total (Total of lines 2 thru 4) |
|||||||||||
| 6 |
|
|||||||||||
| 7 |
|
|
|
|
|
|
|
|||||
| 9 |
TOTAL Account 282 (Total of Lines 5 thru 8) |
|
|
|
|
|
|
|
|
|||
| 10 |
Classification of TOTAL |
|||||||||||
| 11 |
Federal Income Tax |
|
|
|
|
|
|
|
|
|||
| 12 |
State Income Tax |
|
|
|
|
|
|
|
||||
| 13 |
Local Income Tax |
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty |
Account 282 electric balance at the beginning of the year reflects a reduction for (amortization) of non-Citizens transmission related excess deferred federal income taxes in the amount of ($4,309,561).
Account 282 electric balance at the beginning of the year reflects a reduction for (amortization) of Citizens transmission related excess deferred federal income taxes in the amount of ($180,826).
Account 282 non-Citizen transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the beginning of the year was $732,250,020.
Account 282 Citizen transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the beginning of the year was $12,022,715.
Account 282 Citizens SX-PQ transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the beginning of the year was $3,028,935.
Account 282 non-Citizen transmission related excess deferred income tax reserve at the beginning of the year was $376,621,256.
Account 282 Citizen transmission related excess deferred income tax reserve at the beginning of the year was $8,318,012.
|
| (b) Concept: AccumulatedDeferredIncomeTaxesOtherProperty |
Account 282 electric balance at the end of the year reflects a reduction for (amortization) of non-Citizens transmission related excess deferred federal income taxes in the amount of ($4,530,851).
Account 282 electric balance at the end of the year reflects a reduction for (amortization) of Citizens transmission related excess deferred federal income taxes in the amount of ($180,826).
Account 282 non-Citizen transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the end of the year was $771,220,222.
Account 282 Citizens Sunrise transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the end of the year was $11,512,111.
Account 282 Citizens SX-PQ transmission related accumulated deferred income taxes included in electric accumulated deferred income taxes at the end of the year was $3,145,258.
Account 282 non-Citizen transmission related excess deferred income tax reserve at the end of the year was $358,966,142.
Account 282 Citizen transmission related excess deferred income tax reserve at the end of the year was $8,137,186.
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) |
|||||||||||
|
|||||||||||
| CHANGES DURING YEAR | ADJUSTMENTS | ||||||||||
| Debits | Credits | ||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
| 1 | Account 283 | ||||||||||
| 2 |
Electric |
||||||||||
| 3 |
|
(a) |
|
|
|
|
|
|
(b) |
||
| 4 |
|
|
|||||||||
| 9 | TOTAL Electric (Total of lines 3 thru 8) |
|
|
|
|
|
|
||||
| 10 |
Gas |
||||||||||
| 11 |
|
|
|
|
|
|
|
|
|
||
| 12 |
|
|
|||||||||
| 17 | TOTAL Gas (Total of lines 11 thru 16) |
|
|
|
|
|
|
||||
| 18 | TOTAL Other |
|
|
|
|
|
|
|
|
||
| 19 | TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18) |
|
|
|
|
|
|
|
|
||
| 20 |
Classification of TOTAL |
||||||||||
| 21 |
Federal Income Tax |
|
|
|
|
|
|
|
|
||
| 22 |
State Income Tax |
|
|
|
|
|
|
|
|||
| 23 |
Local Income Tax |
|
|||||||||
|
NOTES |
|||||||||||
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredIncomeTaxesOther |
| (b) Concept: AccumulatedDeferredIncomeTaxesOther |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY LIABILITIES (Account 254) |
||||||
|
||||||
| DEBITS | ||||||
| Line No. |
Description and Purpose of Other Regulatory Liabilities (a) |
Balance at Beginning of Current Quarter/Year (b) |
Account Credited (c) |
Amount (d) |
Credits (e) |
Balance at End of Current Quarter/Year (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
|
|
|
| 41 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
Electric Operating Revenues |
|||||||
|
|||||||
| Line No. |
Title of Account (a) |
Operating Revenues Year to Date Quarterly/Annual (b) |
Operating Revenues Previous year (no Quarterly) (c) |
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d) |
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e) |
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f) |
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g) |
|
1 |
SalesOfElectricityHeadingAbstract Sales of Electricity |
||||||
|
2 |
ResidentialSalesAbstract (440) Residential Sales |
|
|
|
|
|
|
|
3 |
CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales |
||||||
|
4 |
CommercialSalesAbstract Small (or Comm.) (See Instr. 4) |
|
|
|
|
|
|
|
5 |
IndustrialSalesAbstract Large (or Ind.) (See Instr. 4) |
|
|
|
|
|
|
|
6 |
PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting |
|
|
|
|
|
|
|
7 |
OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities |
||||||
|
8 |
SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways |
||||||
|
9 |
InterdepartmentalSalesAbstract (448) Interdepartmental Sales |
||||||
|
10 |
SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers |
|
|
|
|
|
|
|
11 |
SalesForResaleAbstract (447) Sales for Resale |
|
|
|
|
||
|
12 |
SalesOfElectricityAbstract TOTAL Sales of Electricity |
|
|
|
|
|
|
|
13 |
ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds |
||||||
|
14 |
RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds |
|
|
|
|
|
|
|
15 |
OtherOperatingRevenuesAbstract Other Operating Revenues |
||||||
|
16 |
ForfeitedDiscounts (450) Forfeited Discounts |
||||||
|
17 |
MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues |
(a) |
(d) |
||||
|
18 |
SalesOfWaterAndWaterPower (453) Sales of Water and Water Power |
||||||
|
19 |
RentFromElectricProperty (454) Rent from Electric Property |
(b) |
(e) |
||||
|
20 |
InterdepartmentalRents (455) Interdepartmental Rents |
||||||
|
21 |
OtherElectricRevenue (456) Other Electric Revenues |
(c) |
(f) |
||||
|
22 |
RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others |
|
|
||||
|
23 |
RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues |
||||||
|
24 |
MiscellaneousRevenue (457.2) Miscellaneous Revenues |
||||||
|
25 |
OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues |
||||||
|
26 |
OtherOperatingRevenues TOTAL Other Operating Revenues |
|
|
||||
|
27 |
ElectricOperatingRevenues TOTAL Electric Operating Revenues |
|
|
||||
| Line12, column (b) includes $ of unbilled revenues. | |||||||
| Line12, column (d) includes MWH relating to unbilled revenues | |||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: MiscellaneousServiceRevenues | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
* Individual balances are less than $250,000
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: RentFromElectricProperty | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: OtherElectricRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
* Individual balances are less than $250,000
* Includes Transmission Revenue Credits of $4,418,332
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: MiscellaneousServiceRevenues | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
* Individual balances are less than $250,000
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: RentFromElectricProperty | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (f) Concept: OtherElectricRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
* Individual balances are less than $250,000
* Includes Transmission Revenue Credits of $3,501,419
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1) |
|||||
|
|||||
| Line No. |
Description of Service (a) |
Balance at End of Quarter 1 (b) |
Balance at End of Quarter 2 (c) |
Balance at End of Quarter 3 (d) |
Balance at End of Year (e) |
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 | |||||
| 21 | |||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 | |||||
| 40 | |||||
| 41 | |||||
| 42 | |||||
| 43 | |||||
| 44 | |||||
| 45 | |||||
| 46 |
TOTAL |
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|||||
| 5 |
|
|
|
|
|
|
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
|
|
| 41 | TOTAL Billed Residential Sales |
|
|
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|||||
| 5 |
|
|
|
|
|
|
| 6 |
|
|||||
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
||||
| 10 |
|
|
|
|
||
| 11 |
|
|
|
|
|
|
| 12 |
|
|
|
|
|
|
| 13 |
|
|
|
|
|
|
| 41 | TOTAL Billed Small or Commercial |
|
|
|
|
|
| 42 | TOTAL Unbilled Rev. Small or Commercial (See Instr. 6) | |||||
| 43 | TOTAL Small or Commercial |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 41 | TOTAL Billed Large (or Ind.) Sales |
|
|
|
|
|
| 42 | TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6) | |||||
| 43 | TOTAL Large (or Ind.) |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 29 | ||||||
| 30 | ||||||
| 31 | ||||||
| 32 | ||||||
| 33 | ||||||
| 34 | ||||||
| 35 | ||||||
| 36 | ||||||
| 37 | ||||||
| 38 | ||||||
| 39 | ||||||
| 40 | ||||||
| 41 | TOTAL Billed Commercial and Industrial Sales | |||||
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 41 | TOTAL Billed Public Street and Highway Lighting |
|
|
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 41 | TOTAL Billed - All Accounts |
|
|
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) - All Accounts | |||||
| 43 | TOTAL - All Accounts |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES FOR RESALE (Account 447) |
|||||||||||
|
|||||||||||
| ACTUAL DEMAND (MW) | REVENUE | ||||||||||
| Line No. |
Name of Company or Public Authority (Footnote Affiliations) (a) |
Statistical Classification (b) |
FERC Rate Schedule or Tariff Number (c) |
Average Monthly Billing Demand (MW) (d) |
Average Monthly NCP Demand (e) |
Average Monthly CP Demand (f) |
Megawatt Hours Sold (g) |
Demand Charges ($) (h) |
Energy Charges ($) (i) |
Other Charges ($) (j) |
Total ($) (h+i+j) (k) |
| 1 |
|
|
|
|
|||||||
| 2 |
|
|
|
|
|
|
|||||
| 3 |
|
|
|
|
|
|
|||||
| 4 |
|
|
|
|
|
|
|||||
| 5 |
|
|
|
|
|
|
|||||
| 6 |
|
|
|
|
|
|
|||||
| 7 |
|
|
|
|
|
|
|||||
| 8 |
|
|
|
|
|
|
|||||
| 9 |
|
|
|
|
|
(a) |
|||||
| 10 |
|
|
|
|
|
|
|||||
| 11 |
|
|
|
|
|
(b) |
|
||||
| 12 |
|
|
|
|
|
|
|||||
| 13 |
|
|
|
|
|
|
|||||
| 14 |
|
|
|
|
|
(c) |
|||||
| 15 |
|
|
|
|
|
|
|||||
| 16 |
|
|
|
|
|
|
|||||
| 17 |
|
|
|
|
|
|
|||||
| 18 |
|
|
|
|
|
|
|||||
| 19 |
|
|
|
|
|
(d) |
|||||
| 20 |
|
|
|
|
|
|
|||||
| 21 |
|
|
|
|
|
|
|||||
| 22 |
|
|
|
|
|
|
|||||
| 23 |
|
|
|
|
|
|
|
||||
| 24 |
|
|
|
|
|
|
|||||
| 15 |
Subtotal - RQ |
||||||||||
| 16 |
Subtotal-Non-RQ |
|
|
|
|
|
|||||
| 17 | Total |
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherChargesRevenueSalesForResale |
| (b) Concept: OtherChargesRevenueSalesForResale |
| (c) Concept: OtherChargesRevenueSalesForResale |
| (d) Concept: OtherChargesRevenueSalesForResale |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC OPERATION AND MAINTENANCE EXPENSES |
|||
|
If the amount for previous year is not derived from previously reported figures, explain in footnote. |
|||
| Line No. |
Account (a) |
Amount for Current Year (b) |
Amount for Previous Year (c) (c) |
|
1 |
PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES |
||
|
2 |
SteamPowerGenerationAbstract A. Steam Power Generation |
||
|
3 |
SteamPowerGenerationOperationAbstract Operation |
||
|
4 |
OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering |
|
|
|
5 |
FuelSteamPowerGeneration (501) Fuel |
|
|
|
6 |
SteamExpensesSteamPowerGeneration (502) Steam Expenses |
|
|
|
7 |
SteamFromOtherSources (503) Steam from Other Sources |
||
|
8 |
SteamTransferredCredit (Less) (504) Steam Transferred-Cr. |
|
|
|
9 |
ElectricExpensesSteamPowerGeneration (505) Electric Expenses |
|
|
|
10 |
MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses |
|
|
|
11 |
RentsSteamPowerGeneration (507) Rents |
|
|
|
12 |
Allowances (509) Allowances |
||
|
13 |
SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12) |
|
|
|
14 |
SteamPowerGenerationMaintenanceAbstract Maintenance |
||
|
15 |
MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering |
|
|
|
16 |
MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures |
|
|
|
17 |
MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant |
|
|
|
18 |
MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant |
|
|
|
19 |
MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant |
|
|
|
20 |
SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19) |
|
|
|
21 |
PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20) |
|
|
|
22 |
NuclearPowerGenerationAbstract B. Nuclear Power Generation |
||
|
23 |
NuclearPowerGenerationOperationAbstract Operation |
||
|
24 |
OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering |
|
|
|
25 |
NuclearFuelExpense (518) Fuel |
||
|
26 |
CoolantsAndWater (519) Coolants and Water |
||
|
27 |
SteamExpensesNuclearPowerGeneration (520) Steam Expenses |
||
|
28 |
SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources |
||
|
29 |
SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr. |
||
|
30 |
ElectricExpensesNuclearPowerGeneration (523) Electric Expenses |
||
|
31 |
MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses |
|
|
|
32 |
RentsNuclearPowerGeneration (525) Rents |
|
|
|
33 |
NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32) |
|
|
|
34 |
NuclearPowerGenerationMaintenanceAbstract Maintenance |
||
|
35 |
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering |
|
|
|
36 |
MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures |
||
|
37 |
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment |
|
|
|
38 |
MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant |
||
|
39 |
MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant |
|
|
|
40 |
NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39) |
|
|
|
41 |
PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40) |
|
|
|
42 |
HydraulicPowerGenerationAbstract C. Hydraulic Power Generation |
||
|
43 |
HydraulicPowerGenerationOperationAbstract Operation |
||
|
44 |
OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering |
||
|
45 |
WaterForPower (536) Water for Power |
||
|
46 |
HydraulicExpenses (537) Hydraulic Expenses |
||
|
47 |
ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses |
||
|
48 |
MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses |
||
|
49 |
RentsHydraulicPowerGeneration (540) Rents |
||
|
50 |
HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49) |
||
|
51 |
HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued) |
||
|
52 |
HydraulicPowerGenerationMaintenanceAbstract Maintenance |
||
|
53 |
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering |
||
|
54 |
MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures |
||
|
55 |
MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways |
||
|
56 |
MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant |
||
|
57 |
MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant |
||
|
58 |
HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57) |
||
|
59 |
PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58) |
||
|
60 |
OtherPowerGenerationAbstract D. Other Power Generation |
||
|
61 |
OtherPowerGenerationOperationAbstract Operation |
||
|
62 |
OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering |
|
|
|
63 |
Fuel (547) Fuel |
|
|
|
64 |
GenerationExpenses (548) Generation Expenses |
||
|
64.1 |
OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment |
||
|
65 |
MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses |
|
|
|
66 |
RentsOtherPowerGeneration (550) Rents |
|
|
|
67 |
OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67) |
|
|
|
68 |
OtherPowerGenerationMaintenanceAbstract Maintenance |
||
|
69 |
MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering |
||
|
70 |
MaintenanceOfStructures (552) Maintenance of Structures |
|
|
|
71 |
MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant |
|
|
|
71.1 |
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment |
||
|
72 |
MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant |
|
|
|
73 |
OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72) |
|
|
|
74 |
PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73) |
|
|
|
75 |
OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses |
||
|
76 |
PurchasedPower (555) Purchased Power |
|
|
|
76.1 |
PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations |
|
|
|
77 |
SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching |
|
|
|
78 |
OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses |
|
|
|
79 |
OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78) |
|
|
|
80 |
PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79) |
|
|
|
81 |
TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES |
||
|
82 |
TransmissionExpensesOperationAbstract Operation |
||
|
83 |
OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering |
|
|
|
85 |
LoadDispatchReliability (561.1) Load Dispatch-Reliability |
|
|
|
86 |
LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System |
|
|
|
87 |
LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling |
|
|
|
88 |
SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services |
|
|
|
89 |
ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development |
|
|
|
90 |
TransmissionServiceStudies (561.6) Transmission Service Studies |
||
|
91 |
GenerationInterconnectionStudies (561.7) Generation Interconnection Studies |
|
|
|
92 |
ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services |
|
|
|
93 |
StationExpensesTransmissionExpense (562) Station Expenses |
|
|
|
93.1 |
OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment |
||
|
94 |
OverheadLineExpense (563) Overhead Lines Expenses |
|
|
|
95 |
UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses |
|
|
|
96 |
TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others |
||
|
97 |
MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses |
|
|
|
98 |
RentsTransmissionElectricExpense (567) Rents |
|
|
|
99 |
TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98) |
|
|
|
100 |
TransmissionMaintenanceAbstract Maintenance |
||
|
101 |
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering |
|
|
|
102 |
MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures |
|
|
|
103 |
MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware |
|
|
|
104 |
MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software |
|
|
|
105 |
MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment |
|
|
|
106 |
MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant |
|
|
|
107 |
MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment |
|
|
|
107.1 |
MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment |
||
|
108 |
MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines |
|
|
|
109 |
MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines |
|
|
|
110 |
MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant |
|
|
|
111 |
TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110) |
|
|
|
112 |
TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111) |
|
|
|
113 |
RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES |
||
|
114 |
RegionalMarketExpensesOperationAbstract Operation |
||
|
115 |
OperationSupervision (575.1) Operation Supervision |
||
|
116 |
DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation |
||
|
117 |
TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation |
||
|
118 |
CapacityMarketAdministration (575.4) Capacity Market Facilitation |
||
|
119 |
AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation |
||
|
120 |
MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance |
||
|
121 |
MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services |
|
|
|
122 |
RentsRegionalMarketExpenses (575.8) Rents |
||
|
123 |
RegionalMarketOperationExpense Total Operation (Lines 115 thru 122) |
|
|
|
124 |
RegionalMarketExpensesMaintenanceAbstract Maintenance |
||
|
125 |
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements |
||
|
126 |
MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware |
||
|
127 |
MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software |
||
|
128 |
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment |
||
|
129 |
MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant |
||
|
130 |
RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129) |
||
|
131 |
RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130) |
|
|
|
132 |
DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES |
||
|
133 |
DistributionExpensesOperationAbstract Operation |
||
|
134 |
OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering |
|
|
|
135 |
LoadDispatching (581) Load Dispatching |
|
|
|
136 |
StationExpensesDistribution (582) Station Expenses |
|
|
|
137 |
OverheadLineExpenses (583) Overhead Line Expenses |
|
|
|
138 |
UndergroundLineExpenses (584) Underground Line Expenses |
|
|
|
138.1 |
OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment |
||
|
139 |
StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses |
|
|
|
140 |
MeterExpenses (586) Meter Expenses |
|
|
|
141 |
CustomerInstallationsExpenses (587) Customer Installations Expenses |
|
|
|
142 |
MiscellaneousDistributionExpenses (588) Miscellaneous Expenses |
|
|
|
143 |
RentsDistributionExpense (589) Rents |
|
|
|
144 |
DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143) |
|
|
|
145 |
DistributionExpensesMaintenanceAbstract Maintenance |
||
|
146 |
MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering |
|
|
|
147 |
MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures |
|
|
|
148 |
MaintenanceOfStationEquipment (592) Maintenance of Station Equipment |
|
|
|
148.1 |
MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment |
||
|
149 |
MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines |
|
|
|
150 |
MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines |
|
|
|
151 |
MaintenanceOfLineTransformers (595) Maintenance of Line Transformers |
|
|
|
152 |
MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems |
|
|
|
153 |
MaintenanceOfMeters (597) Maintenance of Meters |
|
|
|
154 |
MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant |
|
|
|
155 |
DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154) |
|
|
|
156 |
DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155) |
|
|
|
157 |
CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES |
||
|
158 |
CustomerAccountsExpensesOperationsAbstract Operation |
||
|
159 |
SupervisionCustomerAccountExpenses (901) Supervision |
|
|
|
160 |
MeterReadingExpenses (902) Meter Reading Expenses |
|
|
|
161 |
CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses |
|
|
|
162 |
UncollectibleAccounts (904) Uncollectible Accounts |
|
|
|
163 |
MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses |
|
|
|
164 |
CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163) |
|
|
|
165 |
CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES |
||
|
166 |
CustomerServiceAndInformationalExpensesOperationAbstract Operation |
||
|
167 |
SupervisionCustomerServiceAndInformationExpenses (907) Supervision |
||
|
168 |
CustomerAssistanceExpenses (908) Customer Assistance Expenses |
|
|
|
169 |
InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses |
|
|
|
170 |
MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses |
|
|
|
171 |
CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170) |
|
|
|
172 |
SalesExpenseAbstract 7. SALES EXPENSES |
||
|
173 |
SalesExpenseOperationAbstract Operation |
||
|
174 |
SupervisionSalesExpense (911) Supervision |
||
|
175 |
DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses |
|
|
|
176 |
AdvertisingExpenses (913) Advertising Expenses |
||
|
177 |
MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses |
||
|
178 |
SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177) |
|
|
|
179 |
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES |
||
|
180 |
AdministrativeAndGeneralExpensesOperationAbstract Operation |
||
|
181 |
AdministrativeAndGeneralSalaries (920) Administrative and General Salaries |
|
|
|
182 |
OfficeSuppliesAndExpenses (921) Office Supplies and Expenses |
|
|
|
183 |
AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit |
|
|
|
184 |
OutsideServicesEmployed (923) Outside Services Employed |
|
|
|
185 |
PropertyInsurance (924) Property Insurance |
|
|
|
186 |
InjuriesAndDamages (925) Injuries and Damages |
|
|
|
187 |
EmployeePensionsAndBenefits (926) Employee Pensions and Benefits |
|
|
|
188 |
FranchiseRequirements (927) Franchise Requirements |
|
|
|
189 |
RegulatoryCommissionExpenses (928) Regulatory Commission Expenses |
|
|
|
190 |
DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr. |
|
|
|
191 |
GeneralAdvertisingExpenses (930.1) General Advertising Expenses |
|
|
|
192 |
MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses |
|
|
|
193 |
RentsAdministrativeAndGeneralExpense (931) Rents |
|
|
|
194 |
AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193) |
|
|
|
195 |
AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance |
||
|
196 |
MaintenanceOfGeneralPlant (935) Maintenance of General Plant |
|
|
|
197 |
AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196) |
|
|
|
198 |
OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197) |
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
PURCHASED POWER (Account 555) |
||||||||||||||
|
||||||||||||||
| Actual Demand (MW) | POWER EXCHANGES | COST/SETTLEMENT OF POWER | ||||||||||||
| Line No. |
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a) |
StatisticalClassificationCode Statistical Classification (b) |
RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c) |
AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d) |
AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e) |
AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f) |
MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g) |
MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h) |
EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i) |
EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j) |
DemandChargesOfPurchasedPower Demand Charges ($) (k) |
EnergyChargesOfPurchasedPower Energy Charges ($) (l) |
OtherChargesOfPurchasedPower Other Charges ($) (m) |
SettlementOfPower Total (k+l+m) of Settlement ($) (n) |
| 1 | (a) |
|||||||||||||
| 2 | (b) |
|||||||||||||
| 3 | (c) |
|||||||||||||
| 4 | (d) |
|||||||||||||
| 5 | ||||||||||||||
| 6 | (e) |
|||||||||||||
| 7 | ||||||||||||||
| 8 | (f) |
|||||||||||||
| 9 | (g) |
|||||||||||||
| 10 | (h) |
|||||||||||||
| 11 | ||||||||||||||
| 12 | ||||||||||||||
| 13 | ||||||||||||||
| 14 | ||||||||||||||
| 15 | (i) |
|||||||||||||
| 16 | ||||||||||||||
| 17 | (j) |
|||||||||||||
| 18 | (k) |
|||||||||||||
| 19 | (l) |
|||||||||||||
| 20 | ||||||||||||||
| 21 | (m) |
|||||||||||||
| 22 | ||||||||||||||
| 23 | ||||||||||||||
| 24 | ||||||||||||||
| 25 | ||||||||||||||
| 26 | (n) |
|||||||||||||
| 27 | (o) |
|||||||||||||
| 28 | ||||||||||||||
| 29 | (p) |
|||||||||||||
| 30 | (q) |
|||||||||||||
| 31 | ||||||||||||||
| 32 | ||||||||||||||
| 33 | ||||||||||||||
| 34 | ||||||||||||||
| 35 | ||||||||||||||
| 36 | ||||||||||||||
| 37 | (r) |
|||||||||||||
| 38 | (s) |
|||||||||||||
| 39 | (t) |
|||||||||||||
| 40 | (u) |
|||||||||||||
| 41 | ||||||||||||||
| 42 | ||||||||||||||
| 43 | ||||||||||||||
| 44 | (v) |
|||||||||||||
| 45 | ||||||||||||||
| 46 | ||||||||||||||
| 47 | (w) |
|||||||||||||
| 48 | ||||||||||||||
| 49 | (x) |
|||||||||||||
| 50 | (y) |
|||||||||||||
| 51 | (z) |
|||||||||||||
| 52 | (aa) |
|||||||||||||
| 53 | (ab) |
|||||||||||||
| 54 | (ac) |
|||||||||||||
| 55 | ||||||||||||||
| 56 | ||||||||||||||
| 57 | (ad) |
|||||||||||||
| 58 | ||||||||||||||
| 59 | ||||||||||||||
| 60 | ||||||||||||||
| 61 | ||||||||||||||
| 62 | ||||||||||||||
| 63 | ||||||||||||||
| 64 | ||||||||||||||
| 65 | ||||||||||||||
| 66 | ||||||||||||||
| 67 | ||||||||||||||
| 68 | ||||||||||||||
| 69 | ||||||||||||||
| 70 | ||||||||||||||
| 71 | ||||||||||||||
| 72 | (ae) |
|||||||||||||
| 73 | (af) |
|||||||||||||
| 74 | (ag) |
|||||||||||||
| 75 | (ah) |
|||||||||||||
| 76 | (ai) |
|||||||||||||
| 77 | (aj) |
|||||||||||||
| 78 | (ak) |
|||||||||||||
| 79 | (al) |
|||||||||||||
| 80 | ||||||||||||||
| 81 | ||||||||||||||
| 15 | TOTAL |
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: EnergyChargesOfPurchasedPower |
| (b) Concept: EnergyChargesOfPurchasedPower |
| (c) Concept: EnergyChargesOfPurchasedPower |
| (d) Concept: EnergyChargesOfPurchasedPower |
| (e) Concept: EnergyChargesOfPurchasedPower |
| (f) Concept: EnergyChargesOfPurchasedPower |
| (g) Concept: EnergyChargesOfPurchasedPower |
| (h) Concept: EnergyChargesOfPurchasedPower |
| (i) Concept: EnergyChargesOfPurchasedPower |
| (j) Concept: EnergyChargesOfPurchasedPower |
| (k) Concept: EnergyChargesOfPurchasedPower |
| (l) Concept: EnergyChargesOfPurchasedPower |
| (m) Concept: EnergyChargesOfPurchasedPower |
| (n) Concept: EnergyChargesOfPurchasedPower |
| (o) Concept: EnergyChargesOfPurchasedPower |
| (p) Concept: EnergyChargesOfPurchasedPower |
| (q) Concept: EnergyChargesOfPurchasedPower |
| (r) Concept: EnergyChargesOfPurchasedPower |
| (s) Concept: EnergyChargesOfPurchasedPower |
| (t) Concept: EnergyChargesOfPurchasedPower |
| (u) Concept: EnergyChargesOfPurchasedPower |
| (v) Concept: EnergyChargesOfPurchasedPower |
| (w) Concept: EnergyChargesOfPurchasedPower |
| (x) Concept: EnergyChargesOfPurchasedPower |
| (y) Concept: EnergyChargesOfPurchasedPower |
| (z) Concept: EnergyChargesOfPurchasedPower |
| (aa) Concept: EnergyChargesOfPurchasedPower |
| (ab) Concept: EnergyChargesOfPurchasedPower |
| (ac) Concept: EnergyChargesOfPurchasedPower |
| (ad) Concept: EnergyChargesOfPurchasedPower |
| (ae) Concept: EnergyChargesOfPurchasedPower |
| (af) Concept: EnergyChargesOfPurchasedPower |
| (ag) Concept: EnergyChargesOfPurchasedPower |
| (ah) Concept: EnergyChargesOfPurchasedPower |
| (ai) Concept: EnergyChargesOfPurchasedPower |
| (aj) Concept: EnergyChargesOfPurchasedPower |
| (ak) Concept: EnergyChargesOfPurchasedPower |
| (al) Concept: EnergyChargesOfPurchasedPower |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling") |
||||||||||||||
|
||||||||||||||
| TRANSFER OF ENERGY | REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS | |||||||||||||
| Line No. |
PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a) |
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) |
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) |
StatisticalClassificationCode Statistical Classification (d) |
RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e) |
TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f) |
TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g) |
BillingDemand Billing Demand (MW) (h) |
TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i) |
TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j) |
Demand Charges ($) (k) |
Energy Charges ($) (l) |
Other Charges ($) (m) |
RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n) |
| 1 |
|
|
|
|
|
|
|
|
|
|||||
| 35 | TOTAL | |||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY ISO/RTOs |
|||||
|
|||||
| Line No. |
Payment Received by (Transmission Owner Name) (a) |
Statistical Classification (b) |
FERC Rate Schedule or Tariff Number (c) |
Total Revenue by Rate Schedule or Tariff (d) |
Total Revenue (e) |
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 | |||||
| 21 | |||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 | |||||
| 40 | |||||
| 41 | |||||
| 42 | |||||
| 43 | |||||
| 44 | |||||
| 45 | |||||
| 46 | |||||
| 47 | |||||
| 48 | |||||
| 49 | |||||
| 40 |
TOTAL |
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565) |
||||||||
|
||||||||
| TRANSFER OF ENERGY | EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS | |||||||
| Line No. |
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a) |
StatisticalClassificationCode Statistical Classification (b) |
TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c) |
TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d) |
DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e) |
EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f) |
OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g) |
ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h) |
| 1 | ||||||||
| 2 | ||||||||
| 3 | ||||||||
| 4 | ||||||||
| 5 | ||||||||
| 6 | ||||||||
| 7 | ||||||||
| 8 | ||||||||
| 9 | ||||||||
| 10 | ||||||||
| 11 | ||||||||
| 12 | ||||||||
| 13 | ||||||||
| 14 | ||||||||
| 15 | ||||||||
| 16 | ||||||||
|
TOTAL |
||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC) |
||
| Line No. |
Description (a) |
Amount (b) |
| 1 |
IndustryAssociationDues
Industry Association Dues
|
|
| 2 |
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
|
|
| 3 |
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
|
|
| 4 |
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
|
|
| 5 |
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
|
|
| 6 |
|
|
| 7 |
|
|
| 8 |
|
|
| 46 |
MiscellaneousGeneralExpenses
TOTAL
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
||||||
|
||||||
| A. Summary of Depreciation and Amortization Charges | ||||||
| Line No. |
FunctionalClassificationAxis Functional Classification (a) |
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b) |
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c) |
AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d) |
AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e) |
DepreciationAndAmortization Total (f) |
| 1 |
Intangible Plant |
|
|
|||
| 2 |
Steam Production Plant |
|
|
|||
| 3 |
Nuclear Production Plant |
|||||
| 4 |
Hydraulic Production Plant-Conventional |
|||||
| 5 |
Hydraulic Production Plant-Pumped Storage |
|||||
| 6 |
Other Production Plant |
|
|
|||
| 7 |
Transmission Plant |
|
|
|
||
| 8 |
Distribution Plant |
|
|
|
||
| 9 |
Regional Transmission and Market Operation |
|||||
| 10 |
General Plant |
|
|
|||
| 11 |
Common Plant-Electric |
|
|
|
||
| 12 |
TOTAL |
|
|
|
(a) |
|
| B. Basis for Amortization Charges | ||||||
|
|
||||||
| C. Factors Used in Estimating Depreciation Charges | ||||||||
| Line No. |
AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a) |
DepreciablePlantBase Depreciable Plant Base (in Thousands) (b) |
UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c) |
UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d) |
UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e) |
MortalityCurveType Mortality Curve Type (f) |
UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g) |
|
| 12 | ||||||||
| 13 | ||||||||
| 14 | ||||||||
| 15 | ||||||||
| 16 | ||||||||
| 17 | ||||||||
| 18 | ||||||||
| 19 | ||||||||
| 20 | ||||||||
| 21 | ||||||||
| 22 | ||||||||
| 23 | ||||||||
| 24 | ||||||||
| 25 | ||||||||
| 26 | ||||||||
| 27 | ||||||||
| 28 | ||||||||
| 29 | ||||||||
| 30 | ||||||||
| 31 | ||||||||
| 32 | ||||||||
| 33 | ||||||||
| 34 | ||||||||
| 35 | ||||||||
| 36 | ||||||||
| 37 | ||||||||
| 38 | ||||||||
| 39 | ||||||||
| 40 | ||||||||
| 41 | ||||||||
| 42 | ||||||||
| 43 | ||||||||
| 44 | ||||||||
| 45 | ||||||||
| 46 | ||||||||
| 47 | ||||||||
| 48 | ||||||||
| 49 | ||||||||
| 50 | ||||||||
| 51 | ||||||||
| 52 | ||||||||
| 53 | ||||||||
| 54 | ||||||||
| 55 | ||||||||
| 56 | ||||||||
| 57 | ||||||||
| 58 | ||||||||
| 59 | ||||||||
| 60 | ||||||||
| 61 | ||||||||
| 62 | ||||||||
| 63 | ||||||||
| 64 | ||||||||
| 65 | ||||||||
| 66 | ||||||||
| 67 | ||||||||
| 68 | ||||||||
| 69 | ||||||||
| 70 | ||||||||
| 71 | ||||||||
| 72 | ||||||||
| 73 | ||||||||
| 74 | ||||||||
| 75 | ||||||||
| 76 | ||||||||
| 77 | ||||||||
| 78 | ||||||||
| 79 | ||||||||
| 80 | ||||||||
| 81 | ||||||||
| 82 | ||||||||
| 83 | ||||||||
| 84 | ||||||||
| 85 | ||||||||
| 86 | ||||||||
| 87 | ||||||||
| 88 | ||||||||
| 89 | ||||||||
| 90 | ||||||||
| 91 | ||||||||
| 92 | ||||||||
| 93 | ||||||||
| 94 | ||||||||
| 95 | ||||||||
| 96 | ||||||||
| 97 | ||||||||
| 98 | ||||||||
| 99 | ||||||||
| 100 | ||||||||
| 101 | ||||||||
| 102 | ||||||||
| 103 | ||||||||
| 104 | ||||||||
| 105 | ||||||||
| 106 | ||||||||
| 107 | ||||||||
| 108 | ||||||||
| 109 | ||||||||
| 110 | ||||||||
| 111 | ||||||||
| 112 | ||||||||
| 113 | ||||||||
| 114 | ||||||||
| 115 | ||||||||
| 116 | ||||||||
| 117 | ||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DepreciationAndAmortization | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reclassification of 2021 Electric Depreciation and Amortization Charges Depreciation and Amortization Expense Charged in Accordance with FERC Seven Factor Test In Accordance with Guidelines in FERC Order 888
(1) Ties to Line 12 of FERC Form 1, page 336
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGULATORY COMMISSION EXPENSES |
||||||||||||
|
||||||||||||
| EXPENSES INCURRED DURING YEAR | AMORTIZED DURING YEAR | |||||||||||
| CURRENTLY CHARGED TO | ||||||||||||
| Line No. |
RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a) |
RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b) |
RegulatoryExpensesOfUtility Expenses of Utility (c) |
RegulatoryCommissionExpensesAmount Total Expenses for Current Year (d) |
OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e) |
NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f) |
AccountNumberRegulatoryCommissionExpensesCharged Account No. (g) |
RegulatoryComissionExpensesIncurredAndCharged Amount (h) |
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i) |
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j) |
DeferredRegulatoryCommissionExpensesAmortized Amount (k) |
OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l) |
| 1 |
|
|
|
|
|
|
||||||
| 2 |
|
|
|
|
|
|
||||||
| 3 |
|
|
|
|
|
|
||||||
| 4 |
|
|
|
|
|
|
||||||
| 5 |
|
|
|
|
|
|
||||||
| 6 |
|
|
|
|
|
|
||||||
| 7 |
|
|
|
|
|
|
||||||
| 8 |
|
|
|
|
|
|
||||||
| 9 |
|
|
|
|
|
|
||||||
| 10 |
|
|
|
|
|
|
||||||
| 11 |
|
|
|
|
|
|
||||||
| 12 |
|
|
|
|
|
|
||||||
| 13 |
|
|
|
|
|
|
||||||
| 14 |
|
|
|
|
|
|
||||||
| 15 |
|
|
|
|
|
|
||||||
| 16 |
|
|
|
|
|
|
||||||
| 17 |
|
|
|
|
|
|
||||||
| 18 |
|
|
|
|
|
|
||||||
| 19 |
|
|
|
|
|
|
||||||
| 20 |
|
|
|
|
|
|
||||||
| 21 |
|
|
|
|
|
|
||||||
| 22 |
|
|
|
|
|
|
||||||
| 23 |
|
|
|
|
|
|
||||||
| 24 |
|
|
|
|
|
|
||||||
| 25 |
|
|
|
|
|
|
||||||
| 26 |
|
|
|
|
|
|
||||||
| 27 |
|
|
|
|
|
|
||||||
| 28 |
|
|
|
|
|
|
||||||
| 29 |
|
|
|
|
|
|
||||||
| 30 |
|
|
|
|
|
|
||||||
| 31 |
|
|
|
|
|
|
||||||
| 32 |
|
|
|
|
|
|
||||||
| 33 |
|
|
|
|
|
|
||||||
| 34 |
|
|
|
|
|
|
||||||
| 35 |
|
|
|
|
|
|
||||||
| 36 |
|
|
|
|
|
|
||||||
| 37 |
|
|
|
|
|
|
||||||
| 38 |
|
|
|
|
|
|
||||||
| 39 |
|
|
|
|
|
|
||||||
| 40 |
|
|
|
|
|
|
||||||
| 41 |
|
|
|
|
|
|
||||||
| 42 |
|
|
|
|
|
|
||||||
| 43 |
|
|
|
|
|
|
||||||
| 44 |
|
|
|
|
|
|
||||||
| 45 |
|
|
|
|
|
|
||||||
| 46 |
|
|
|
|
|
|
||||||
| 47 |
|
|
|
|
|
|
||||||
| 48 |
|
|
|
|
|
|
||||||
| 49 |
|
|
|
|
|
|
||||||
| 50 |
|
|
|
|
|
|
||||||
| 51 |
|
|
|
|
|
|
||||||
| 52 |
|
|
|
|
|
|
||||||
| 53 |
|
|
|
|
|
|
||||||
| 54 |
|
|
|
|
|
|
||||||
| 55 |
|
|
|
|
|
|
||||||
| 56 |
|
|
|
|
|
|
||||||
| 57 |
|
|
|
|
|
|
||||||
| 58 |
|
|
|
|
|
|
||||||
| 59 |
|
|
|
|
|
|
||||||
| 60 |
|
|
|
|
|
|
||||||
| 61 |
|
|
|
|
|
|
||||||
| 62 |
|
|
|
|
|
|
||||||
| 63 |
|
|
|
|
|
|
||||||
| 64 |
|
|
|
|
|
|
||||||
| 65 |
|
|
|
|
|
|
||||||
| 66 |
|
|
|
|
|
|
||||||
| 67 |
|
|
|
|
|
|
||||||
| 68 |
|
|
|
|
|
|
||||||
| 69 |
|
|
|
|
|
|
||||||
| 70 |
|
|
|
|
|
|
||||||
| 71 |
|
|
|
|
|
|
||||||
| 72 |
|
|
|
|
|
|
||||||
| 73 |
|
|
|
|
|
|
||||||
| 74 |
|
|
|
|
|
|
||||||
| 75 |
|
|
|
|
|
|
||||||
| 76 |
|
|
|
|
|
|
||||||
| 77 |
|
|
|
|
|
|
||||||
| 78 |
|
|
|
|
|
|
||||||
| 79 |
|
|
|
|
|
|
||||||
| 80 |
|
|
|
|
|
|
||||||
| 81 |
|
|
|
|
|
|
||||||
| 82 |
|
|
|
|
|
|
||||||
| 83 |
|
|
|
|
|
|
||||||
| 84 |
|
|
|
|
|
|
||||||
| 85 |
|
|
|
|
|
|
||||||
| 86 |
|
|
|
|
|
|
||||||
| 87 |
|
|
|
|
|
|
||||||
| 88 |
|
|
|
|
|
|
||||||
| 89 |
|
|
|
|
|
|
||||||
| 90 |
|
|
|
|
|
|
||||||
| 91 |
|
|
|
|
|
|
||||||
| 92 |
|
|
|
|
|
|
||||||
| 93 |
|
|
|
|
|
|
||||||
| 94 |
|
|
|
|
|
|
||||||
| 95 |
|
|
|
|
|
|
||||||
| 96 |
|
|
|
|
|
|
||||||
| 97 |
|
|
|
|
|
|
||||||
| 98 |
|
|
|
|
|
|
||||||
| 46 |
TOTAL |
|
|
|
|
|||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES |
|||||||
|
|||||||
| AMOUNTS CHARGED IN CURRENT YEAR | |||||||
| Line No. |
ResearchDevelopmentAndDemonstrationClassification Classification (a) |
ResearchDevelopmentAndDemonstrationDescription Description (b) |
ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c) |
ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d) |
AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e) |
ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f) |
ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g) |
| 1 | |||||||
| 2 | |||||||
| 3 | |||||||
| 4 | |||||||
| 5 | |||||||
| 6 | |||||||
| 7 | |||||||
| 8 | |||||||
| 9 | |||||||
| 10 | |||||||
| 11 | |||||||
| 12 | |||||||
| 13 | |||||||
| 14 | |||||||
| 15 | |||||||
| 16 | |||||||
| 17 | |||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
DISTRIBUTION OF SALARIES AND WAGES |
|||||
|
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. |
|||||
| Line No. |
Classification (a) |
Direct Payroll Distribution (b) |
Allocation of Payroll Charged for Clearing Accounts (c) |
Total (d) |
|
|
1 |
SalariesAndWagesElectricAbstract Electric |
||||
|
2 |
SalariesAndWagesElectricOperationAbstract Operation |
||||
|
3 |
SalariesAndWagesElectricOperationProduction Production |
|
|||
|
4 |
SalariesAndWagesElectricOperationTransmission Transmission |
|
|||
|
5 |
SalariesAndWagesElectricOperationRegionalMarket Regional Market |
||||
|
6 |
SalariesAndWagesElectricOperationDistribution Distribution |
|
|||
|
7 |
SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts |
|
|||
|
8 |
SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational |
|
|||
|
9 |
SalariesAndWagesElectricOperationSales Sales |
||||
|
10 |
SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General |
|
|||
|
11 |
SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10) |
|
|||
|
12 |
SalariesAndWagesElectricMaintenanceAbstract Maintenance |
||||
|
13 |
SalariesAndWagesElectricMaintenanceProduction Production |
|
|||
|
14 |
SalariesAndWagesElectricMaintenanceTransmission Transmission |
|
|||
|
15 |
SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market |
||||
|
16 |
SalariesAndWagesElectricMaintenanceDistribution Distribution |
|
|||
|
17 |
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General |
|
|||
|
18 |
SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17) |
|
|||
|
19 |
SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance |
||||
|
20 |
SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13) |
|
|||
|
21 |
SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14) |
|
|||
|
22 |
SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15) |
||||
|
23 |
SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16) |
|
|||
|
24 |
SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7) |
|
|||
|
25 |
SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8) |
|
|||
|
26 |
SalariesAndWagesElectricSales Sales (Transcribe from line 9) |
||||
|
27 |
SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17) |
|
|||
|
28 |
SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27) |
|
|
|
|
|
29 |
SalariesAndWagesGasAbstract Gas |
||||
|
30 |
SalariesAndWagesGasOperationAbstract Operation |
||||
|
31 |
SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas |
||||
|
32 |
SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.) |
||||
|
33 |
SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply |
||||
|
34 |
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing |
|
|||
|
35 |
SalariesAndWagesGasOperationTransmission Transmission |
|
|||
|
36 |
SalariesAndWagesGasOperationDistribution Distribution |
|
|||
|
37 |
SalariesAndWagesGasCustomerAccounts Customer Accounts |
|
|||
|
38 |
SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational |
|
|||
|
39 |
SalariesAndWagesGasSales Sales |
||||
|
40 |
SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General |
|
|||
|
41 |
SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40) |
|
|||
|
42 |
SalariesAndWagesGasMaintenanceAbstract Maintenance |
||||
|
43 |
SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas |
||||
|
44 |
SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development) |
||||
|
45 |
SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply |
||||
|
46 |
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing |
||||
|
47 |
SalariesAndWagesGasMaintenanceTransmission Transmission |
|
|||
|
48 |
SalariesAndWagesGasMaintenanceDistribution Distribution |
|
|||
|
49 |
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General |
|
|||
|
50 |
SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49) |
|
|||
|
51 |
SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance |
||||
|
52 |
SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43) |
||||
|
53 |
SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32, |
||||
|
54 |
SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45) |
||||
|
55 |
SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru |
|
|||
|
56 |
SalariesAndWagesGasTransmission Transmission (Lines 35 and 47) |
|
|||
|
57 |
SalariesAndWagesGasDistribution Distribution (Lines 36 and 48) |
|
|||
|
58 |
SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37) |
|
|||
|
59 |
SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38) |
|
|||
|
60 |
SalariesAndWagesGasSales Sales (Line 39) |
||||
|
61 |
SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49) |
|
|||
|
62 |
SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61) |
|
|
|
|
|
63 |
SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments |
||||
|
64 |
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance |
||||
|
65 |
SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64) |
|
|
|
|
|
66 |
SalariesAndWagesUtilityPlantAbstract Utility Plant |
||||
|
67 |
SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments) |
||||
|
68 |
SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant |
|
|
|
|
|
69 |
SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant |
|
|
|
|
|
70 |
SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote): |
||||
|
71 |
SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70) |
|
|
|
|
|
72 |
SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments) |
||||
|
73 |
SalariesAndWagesPlantRemovalElectricPlant Electric Plant |
|
|
|
|
|
74 |
SalariesAndWagesPlantRemovalGasPlant Gas Plant |
|
|
|
|
|
75 |
SalariesAndWagesPlantRemovalOther Other (provide details in footnote): |
||||
|
76 |
SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75) |
|
|
|
|
|
77 |
SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote): |
||||
|
78 |
SalariesAndWagesOtherAccountsDescription |
||||
|
79 |
SalariesAndWagesOtherAccountsDescription |
|
|
|
|
|
80 |
SalariesAndWagesOtherAccountsDescription |
|
|
|
|
|
81 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
82 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
83 |
SalariesAndWagesOtherAccountsDescription |
||||
|
84 |
SalariesAndWagesOtherAccountsDescription |
||||
|
85 |
SalariesAndWagesOtherAccountsDescription |
||||
|
86 |
SalariesAndWagesOtherAccountsDescription |
||||
|
87 |
SalariesAndWagesOtherAccountsDescription |
||||
|
88 |
SalariesAndWagesOtherAccountsDescription |
||||
|
89 |
SalariesAndWagesOtherAccountsDescription |
||||
|
90 |
SalariesAndWagesOtherAccountsDescription |
||||
|
91 |
SalariesAndWagesOtherAccountsDescription |
||||
|
92 |
SalariesAndWagesOtherAccountsDescription |
||||
|
93 |
SalariesAndWagesOtherAccountsDescription |
||||
|
94 |
SalariesAndWagesOtherAccountsDescription |
||||
|
95 |
SalariesAndWagesOtherAccounts TOTAL Other Accounts |
|
|
|
|
|
96 |
SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES |
|
|
(a) |
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: SalariesAndWagesGeneralExpense |
FERC accounts 417 and 426 are not included in the detail classification lines or summary totals.
FERC 417 for 2021 amounts to $3,110,104
FERC 426 for 2021 amounts to $1,280,345
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMMON UTILITY PLANT AND EXPENSES |
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
(1)Ad Valorem Taxes on property are assessed by the State Board of Equalization and consist of one-half of the taxes from each fiscal tax year 2020-2021 and 2021-2022. Ad Valorem Taxes are assessed on the entire operating unit, therefore, assessed taxes are not available by account number. Ad Valorem Taxes are allocated based on procedures adopted by the California Public Utilities Commission. (2)The Common Utility Plant and Accumulated Depreciation is allocated between the Electric and Gas Departments based on labor ratios in accordance with allocation procedures adopted by the California Public Utilities Commission. These rates were revised in January 2021. Other expenses of operation, maintenance and rents for common utility plant are allocated based on labor percentage studies. Specific amounts charged to operations and maintenance are not readily available. |
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS |
|||||
|
|||||
| Line No. |
Description of Item(s) (a) |
Balance at End of Quarter 1 (b) |
Balance at End of Quarter 2 (c) |
Balance at End of Quarter 3 (d) |
Balance at End of Year (e) |
| 1 | Energy | ||||
| 2 | Net Purchases (Account 555) |
|
|
|
|
| 2.1 | Net Purchases (Account 555.1) | ||||
| 3 | Net Sales (Account 447) |
|
|
|
|
| 4 | Transmission Rights | ||||
| 5 | Ancillary Services |
|
|
|
|
| 6 | Other Items (list separately) | ||||
| 7 |
|
|
|
|
|
| 8 |
|
|
|
|
|
| 9 |
|
|
|
|
|
| 10 |
|
|
|
|
|
| 11 |
|
|
|
|
|
| 46 | TOTAL |
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
PURCHASES AND SALES OF ANCILLARY SERVICES |
|||||||
|
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure.
|
|||||||
| Amount Purchased for the Year | Amount Sold for the Year | ||||||
| Usage - Related Billing Determinant | Usage - Related Billing Determinant | ||||||
| Line No. |
Type of Ancillary Service (a) |
Number of Units (b) |
Unit of Measure (c) |
Dollar (d) |
Number of Units (e) |
Unit of Measure (f) |
Dollars (g) |
| 1 |
Scheduling, System Control and Dispatch |
|
|
|
|
|
|
| 2 |
Reactive Supply and Voltage |
||||||
| 3 |
Regulation and Frequency Response |
||||||
| 4 |
Energy Imbalance |
||||||
| 5 |
Operating Reserve - Spinning |
||||||
| 6 |
Operating Reserve - Supplement |
||||||
| 7 |
Other |
||||||
| 8 |
Total (Lines 1 thru 7) |
|
|
|
|
||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY TRANSMISSION SYSTEM PEAK LOAD |
||||||||||
|
||||||||||
| Line No. |
Month (a) |
Monthly Peak MW - Total (b) |
Day of Monthly Peak (c) |
Hour of Monthly Peak (d) |
Firm Network Service for Self (e) |
Firm Network Service for Others (f) |
Long-Term Firm Point-to-point Reservations (g) |
Other Long-Term Firm Service (h) |
Short-Term Firm Point-to-point Reservation (i) |
Other Service (j) |
NAME OF SYSTEM: 0 |
||||||||||
1 |
January |
|
||||||||
2 |
February |
|
||||||||
3 |
March |
|
||||||||
4 |
Total for Quarter 1 |
|||||||||
5 |
April |
|
||||||||
6 |
May |
|
||||||||
7 |
June |
|
||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|
||||||||
10 |
August |
|
||||||||
11 |
September |
|
||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|
||||||||
14 |
November |
|
||||||||
15 |
December |
|
||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Monthly ISO/RTO Transmission System Peak Load |
||||||||||
|
||||||||||
| Line No. |
Month (a) |
Monthly Peak MW - Total (b) |
Day of Monthly Peak (c) |
Hour of Monthly Peak (d) |
Import into ISO/RTO (e) |
Exports from ISO/RTO (f) |
Through and Out Service (g) |
Network Service Usage (h) |
Point-to-Point Service Usage (i) |
Total Usage (j) |
NAME OF SYSTEM: 0 |
||||||||||
1 |
January |
|||||||||
2 |
February |
|||||||||
3 |
March |
|||||||||
4 |
Total for Quarter 1 |
|||||||||
5 |
April |
|||||||||
6 |
May |
|||||||||
7 |
June |
|||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|||||||||
10 |
August |
|||||||||
11 |
September |
|||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|||||||||
14 |
November |
|||||||||
15 |
December |
|||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total Year to Date/Year |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ELECTRIC ENERGY ACCOUNT |
|||||
|
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year. |
|||||
| Line No. |
Item
(a)
|
MegaWatt Hours
(b)
|
Line No. |
Item
(a)
|
MegaWatt Hours
(b)
|
| 1 |
SOURCES OF ENERGY |
21 |
DISPOSITION OF ENERGY |
||
| 2 |
Generation (Excluding Station Use): |
22 |
Sales to Ultimate Consumers (Including Interdepartmental Sales) |
|
|
| 3 |
Steam |
|
23 |
Requirements Sales for Resale (See instruction 4, page 311.) |
|
| 4 |
Nuclear |
24 |
Non-Requirements Sales for Resale (See instruction 4, page 311.) |
|
|
| 5 |
Hydro-Conventional |
25 |
Energy Furnished Without Charge |
||
| 6 |
Hydro-Pumped Storage |
|
26 |
Energy Used by the Company (Electric Dept Only, Excluding Station Use) |
|
| 7 |
Other |
|
27 |
Total Energy Losses |
|
| 8 |
Less Energy for Pumping |
|
27.1 |
Total Energy Stored |
|
| 9 |
Net Generation (Enter Total of lines 3 through 8) |
|
28 |
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES |
|
| 10 |
Purchases (other than for Energy Storage) |
|
|||
| 10.1 |
Purchases for Energy Storage |
|
|||
| 11 |
Power Exchanges: |
||||
| 12 |
Received |
|
|||
| 13 |
Delivered |
|
|||
| 14 |
Net Exchanges (Line 12 minus line 13) |
|
|||
| 15 |
Transmission For Other (Wheeling) |
||||
| 16 |
Received |
||||
| 17 |
Delivered |
||||
| 18 |
Net Transmission for Other (Line 16 minus line 17) |
|
|||
| 19 |
Transmission By Others Losses |
||||
| 20 |
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19) |
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY PEAKS AND OUTPUT |
||||||
|
||||||
| Line No. |
MonthAxis Month (a) |
EnergyActivity Total Monthly Energy (b) |
NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c) |
MonthlyPeakLoad Monthly Peak - Megawatts (d) |
DayOfMonthlyPeak Monthly Peak - Day of Month (e) |
HourOfMonthlyPeak Monthly Peak - Hour (f) |
NAME OF SYSTEM: 0 |
||||||
29 |
January |
|
||||
30 |
February |
|
||||
31 |
March |
|
||||
32 |
April |
|
||||
33 |
May |
|
||||
34 |
June |
|
||||
35 |
July |
|
||||
36 |
August |
|
||||
37 |
September |
|
||||
38 |
October |
|
||||
39 |
November |
|
||||
40 |
December |
|
||||
41 |
Total |
|
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Steam Electric Generating Plant Statistics |
|
1. Report data for plant in Service only. |
| Line No. |
Item
(a)
|
Plant Name:
|
Plant Name:
|
Plant Name:
|
Plant Name:
|
| 1 |
PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear) |
|
|
|
|
| 2 |
PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc) |
|
|
|
|
| 3 |
YearPlantOriginallyConstructed Year Originally Constructed |
|
|
|
|
| 4 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
|
|
|
|
| 5 |
InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW) |
|
|
|
|
| 6 |
NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes) |
|
|
|
|
| 7 |
PlantHoursConnectedToLoad Plant Hours Connected to Load |
|
|
|
|
| 8 |
NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts) |
|
|
|
|
| 9 |
NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water |
|
|
|
|
| 10 |
NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water |
|
|
|
|
| 11 |
PlantAverageNumberOfEmployees Average Number of Employees |
|
|
|
|
| 12 |
NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |
|
|
|
|
| 13 |
CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights |
|
|||
| 14 |
CostOfStructuresAndImprovementsSteamProduction Structures and Improvements |
|
|
|
|
| 15 |
CostOfEquipmentSteamProduction Equipment Costs |
|
|
|
|
| 16 |
AssetRetirementCostsSteamProduction Asset Retirement Costs |
|
|||
| 17 |
CostOfPlant Total cost (total 13 thru 20) |
|
|
|
|
| 18 |
CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including |
|
|
|
|
| 19 |
OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr |
|
|
|
|
| 20 |
FuelSteamPowerGeneration Fuel |
|
|
|
|
| 21 |
CoolantsAndWater Coolants and Water (Nuclear Plants Only) |
||||
| 22 |
SteamExpensesSteamPowerGeneration Steam Expenses |
|
|
|
|
| 23 |
SteamFromOtherSources Steam From Other Sources |
||||
| 24 |
SteamTransferredCredit Steam Transferred (Cr) |
|
|||
| 25 |
ElectricExpensesSteamPowerGeneration Electric Expenses |
|
|
|
|
| 26 |
MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses |
||||
| 27 |
RentsSteamPowerGeneration Rents |
|
|||
| 28 |
Allowances Allowances |
||||
| 29 |
MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering |
||||
| 30 |
MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures |
|
|
||
| 31 |
MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant |
|
|
||
| 32 |
MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant |
|
|
|
|
| 33 |
MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant |
|
|
|
|
| 34 |
PowerProductionExpensesSteamPower Total Production Expenses |
|
|
|
|
| 35 |
ExpensesPerNetKilowattHour Expenses per Net kWh |
|
|
|
|
| 35 |
FuelKindAxis Plant Name |
Cuyamaca |
Desert Star |
Miramar |
Palomar |
| 36 |
FuelKind Fuel Kind |
|
|
|
|
| 37 |
FuelUnit Fuel Unit |
|
|
|
|
| 38 |
QuantityOfFuelBurned Quantity (Units) of Fuel Burned |
|
|
|
|
| 39 |
FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) |
|
|
||
| 40 |
AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year |
||||
| 41 |
AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned |
|
|
|
|
| 42 |
AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU |
|
|
|
|
| 43 |
AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen |
|
|
|
|
| 44 |
AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation |
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Hydroelectric Generating Plant Statistics |
|
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
| 1 |
PlantKind Kind of Plant (Run-of-River or Storage) |
|
| 2 |
PlantConstructionType Plant Construction type (Conventional or Outdoor) |
|
| 3 |
YearPlantOriginallyConstructed Year Originally Constructed |
|
| 4 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
|
| 5 |
InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |
|
| 6 |
NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes) |
|
| 7 |
PlantHoursConnectedToLoad Plant Hours Connect to Load |
|
| 8 |
NetPlantCapabilityAbstract Net Plant Capability (in megawatts) |
|
| 9 |
NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions |
|
| 10 |
NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions |
|
| 11 |
PlantAverageNumberOfEmployees Average Number of Employees |
|
| 12 |
NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |
|
| 13 |
CostOfPlantAbstract Cost of Plant |
|
| 14 |
CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights |
|
| 15 |
CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements |
|
| 16 |
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways |
|
| 17 |
EquipmentCostsHydroelectricProduction Equipment Costs |
|
| 18 |
CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges |
|
| 19 |
AssetRetirementCostsHydroelectricProduction Asset Retirement Costs |
|
| 20 |
CostOfPlant Total cost (total 13 thru 20) |
|
| 21 |
CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5) |
|
| 22 |
ProductionExpensesAbstract Production Expenses |
|
| 23 |
OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |
|
| 24 |
WaterForPower Water for Power |
|
| 25 |
HydraulicExpenses Hydraulic Expenses |
|
| 26 |
ElectricExpensesHydraulicPowerGeneration Electric Expenses |
|
| 27 |
MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses |
|
| 28 |
RentsHydraulicPowerGeneration Rents |
|
| 29 |
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering |
|
| 30 |
MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures |
|
| 31 |
MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways |
|
| 32 |
MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant |
|
| 33 |
MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant |
|
| 34 |
PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33) |
|
| 35 |
ExpensesPerNetKilowattHour Expenses per net kWh |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Pumped Storage Generating Plant Statistics |
|||||||
|
|||||||
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
|||||
| 1 |
PlantConstructionType Type of Plant Construction (Conventional or Outdoor) |
||||||
| 2 |
YearPlantOriginallyConstructed Year Originally Constructed |
||||||
| 3 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
||||||
| 4 |
InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |
||||||
| 5 |
NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes) |
|
|||||
| 6 |
PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating |
|
|||||
| 7 |
NetContinuousPlantCapability Net Plant Capability (in megawatts) |
|
|||||
| 8 |
PlantAverageNumberOfEmployees Average Number of Employees |
||||||
| 9 |
NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh |
|
|||||
| 10 |
EnergyUsedForPumping Energy Used for Pumping |
||||||
| 11 |
NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh |
|
|||||
| 12 |
CostOfPlantAbstract Cost of Plant |
||||||
| 13 |
CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights |
||||||
| 14 |
CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements |
|
|||||
| 15 |
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways |
|
|||||
| 16 |
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators |
|
|||||
| 17 |
CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment |
|
|||||
| 18 |
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment |
|
|||||
| 19 |
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges |
|
|||||
| 20 |
AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs |
|
|||||
| 21 |
CostOfPlant Total cost (total 13 thru 20) |
||||||
| 22 |
CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4) |
||||||
| 23 |
ProductionExpensesAbstract Production Expenses |
||||||
| 24 |
OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |
|
|||||
| 25 |
WaterForPower Water for Power |
|
|||||
| 26 |
PumpedStorageExpenses Pumped Storage Expenses |
|
|||||
| 27 |
ElectricExpensesPumpedStoragePlant Electric Expenses |
|
|||||
| 28 |
MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses |
|
|||||
| 29 |
RentsPumpedStoragePlant Rents |
|
|||||
| 30 |
MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering |
|
|||||
| 31 |
MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures |
|
|||||
| 32 |
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways |
|
|||||
| 33 |
MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant |
|
|||||
| 34 |
MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant |
|
|||||
| 35 |
PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34) |
||||||
| 36 |
PumpingExpenses Pumping Expenses |
||||||
| 37 |
PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36) |
||||||
| 38 |
ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9) |
||||||
| 39 |
ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10)) |
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
GENERATING PLANT STATISTICS (Small Plants) |
|||||||||||||
|
|||||||||||||
| Production Expenses | |||||||||||||
| Line No. |
PlantName Name of Plant (a) |
YearPlantOriginallyConstructed Year Orig. Const. (b) |
InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c) |
NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d) |
NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e) |
CostOfPlant Cost of Plant (f) |
PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g) |
OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h) |
FuelProductionExpenses Fuel Production Expenses (i) |
MaintenanceProductionExpenses Maintenance Production Expenses (j) |
FuelKind Kind of Fuel (k) |
FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l) |
GenerationType Generation Type (m) |
| 1 | |||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ENERGY STORAGE OPERATIONS (Large Plants) |
|||||||||||||||||||
|
|||||||||||||||||||
| Line No. |
Name of the Energy Storage Project (a) |
Functional Classification (b) |
Location of the Project (c) |
MWHs (d) |
MWHs delivered to the grid to support Production (e) |
MWHs delivered to the grid to support Transmission (f) |
MWHs delivered to the grid to support Distribution (g) |
MWHs Lost During Conversion, Storage and Discharge of Energy Production (h) |
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i) |
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j) |
MWHs Sold (k) |
Revenues from Energy Storage Operations (l) |
Power Purchased for Storage Operations (555.1) (Dollars) (m) |
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n) |
Other Costs Associated with Self-Generated Power (Dollars) (o) |
Project Costs included in (p) |
Production (Dollars) (q) |
Transmission (Dollars) (r) |
Distribution (Dollars) (s) |
| 1 | |||||||||||||||||||
| 2 | |||||||||||||||||||
| 3 | |||||||||||||||||||
| 4 | |||||||||||||||||||
| 5 | |||||||||||||||||||
| 6 | |||||||||||||||||||
| 7 | |||||||||||||||||||
| 8 | |||||||||||||||||||
| 9 | |||||||||||||||||||
| 10 | |||||||||||||||||||
| 11 | |||||||||||||||||||
| 12 | |||||||||||||||||||
| 13 | |||||||||||||||||||
| 14 | |||||||||||||||||||
| 15 | |||||||||||||||||||
| 16 | |||||||||||||||||||
| 17 | |||||||||||||||||||
| 18 | |||||||||||||||||||
| 19 | |||||||||||||||||||
| 20 | |||||||||||||||||||
| 21 | |||||||||||||||||||
| 22 | |||||||||||||||||||
| 23 | |||||||||||||||||||
| 24 | |||||||||||||||||||
| 25 | |||||||||||||||||||
| 26 | |||||||||||||||||||
| 27 | |||||||||||||||||||
| 28 | |||||||||||||||||||
| 29 | |||||||||||||||||||
| 30 | |||||||||||||||||||
| 31 | |||||||||||||||||||
| 32 | |||||||||||||||||||
| 33 | |||||||||||||||||||
| 34 | |||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINE STATISTICS |
||||||||||||||||
|
||||||||||||||||
| DESIGNATION | VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) | LENGTH (Pole miles) - (In the case of underground lines report circuit miles) | COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) | EXPENSES, EXCEPT DEPRECIATION AND TAXES | ||||||||||||
| Line No. |
TransmissionLineStartPoint From |
TransmissionLineEndPoint To |
OperatingVoltageOfTransmissionLine Operating |
DesignedVoltageOfTransmissionLine Designated |
SupportingStructureOfTransmissionLineType Type of Supporting Structure |
LengthForStandAloneTransmissionLines On Structure of Line Designated |
LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line |
NumberOfTransmissionCircuits Number of Circuits |
SizeOfConductorAndMaterial Size of Conductor and Material |
CostOfLandAndLandRightsTransmissionLines Land |
ConstructionAndOtherCostsTransmissionLines Construction Costs |
OverallCostOfTransmissionLine Total Costs |
OperatingExpensesOfTransmissionLine Operation Expenses |
MaintenanceExpensesOfTransmissionLine Maintenance Expenses |
RentExpensesOfTransmissionLine Rents |
OverallExpensesOfTransmissionLine Total Expenses |
|
(a) |
(b) |
(c) |
(d) |
(e) |
(f) |
(g) |
(h) |
(i) |
(j) |
(k) |
(l) |
(m) |
(n) |
(o) |
(p) |
|
| 1 | ||||||||||||||||
| 2 | (a) |
|||||||||||||||
| 3 | (b) |
|||||||||||||||
| 4 | (c) |
|||||||||||||||
| 5 | ||||||||||||||||
| 6 | ||||||||||||||||
| 7 | ||||||||||||||||
| 8 | ||||||||||||||||
| 9 | ||||||||||||||||
| 10 | ||||||||||||||||
| 11 | ||||||||||||||||
| 12 | ||||||||||||||||
| 13 | ||||||||||||||||
| 14 | ||||||||||||||||
| 15 | ||||||||||||||||
| 16 | ||||||||||||||||
| 17 | ||||||||||||||||
| 18 | ||||||||||||||||
| 19 | ||||||||||||||||
| 20 | ||||||||||||||||
| 21 | ||||||||||||||||
| 22 | ||||||||||||||||
| 23 | ||||||||||||||||
| 24 | ||||||||||||||||
| 25 | ||||||||||||||||
| 26 | ||||||||||||||||
| 27 | ||||||||||||||||
| 28 | ||||||||||||||||
| 29 | ||||||||||||||||
| 30 | ||||||||||||||||
| 31 | ||||||||||||||||
| 32 | ||||||||||||||||
| 33 | ||||||||||||||||
| 34 | ||||||||||||||||
| 35 | ||||||||||||||||
| 36 | ||||||||||||||||
| 37 | ||||||||||||||||
| 38 | ||||||||||||||||
| 39 | ||||||||||||||||
| 40 | ||||||||||||||||
| 41 | ||||||||||||||||
| 42 | ||||||||||||||||
| 43 | ||||||||||||||||
| 44 | ||||||||||||||||
| 45 | ||||||||||||||||
| 46 | ||||||||||||||||
| 47 | ||||||||||||||||
| 48 | ||||||||||||||||
| 49 | ||||||||||||||||
| 50 | ||||||||||||||||
| 51 | ||||||||||||||||
| 52 | ||||||||||||||||
| 53 | ||||||||||||||||
| 54 | ||||||||||||||||
| 55 | ||||||||||||||||
| 56 | ||||||||||||||||
| 57 | ||||||||||||||||
| 58 | ||||||||||||||||
| 59 | ||||||||||||||||
| 60 | ||||||||||||||||
| 61 | ||||||||||||||||
| 62 | ||||||||||||||||
| 63 | ||||||||||||||||
| 64 | ||||||||||||||||
| 65 | ||||||||||||||||
| 66 | ||||||||||||||||
| 67 | ||||||||||||||||
| 68 | ||||||||||||||||
| 69 | ||||||||||||||||
| 70 | ||||||||||||||||
| 71 | ||||||||||||||||
| 72 | ||||||||||||||||
| 73 | ||||||||||||||||
| 74 | ||||||||||||||||
| 75 | ||||||||||||||||
| 76 | ||||||||||||||||
| 77 | ||||||||||||||||
| 78 | ||||||||||||||||
| 79 | ||||||||||||||||
| 80 | ||||||||||||||||
| 81 | ||||||||||||||||
| 82 | ||||||||||||||||
| 83 | ||||||||||||||||
| 84 | ||||||||||||||||
| 85 | ||||||||||||||||
| 86 | ||||||||||||||||
| 87 | ||||||||||||||||
| 88 | ||||||||||||||||
| 89 | ||||||||||||||||
| 90 | ||||||||||||||||
| 91 | ||||||||||||||||
| 92 | ||||||||||||||||
| 93 | ||||||||||||||||
| 94 | ||||||||||||||||
| 95 | ||||||||||||||||
| 96 | ||||||||||||||||
| 97 | ||||||||||||||||
| 98 | ||||||||||||||||
| 99 | ||||||||||||||||
| 100 | ||||||||||||||||
| 101 | ||||||||||||||||
| 102 | ||||||||||||||||
| 103 | ||||||||||||||||
| 104 | ||||||||||||||||
| 105 | ||||||||||||||||
| 106 | ||||||||||||||||
| 107 | ||||||||||||||||
| 108 | ||||||||||||||||
| 109 | ||||||||||||||||
| 110 | ||||||||||||||||
| 111 | ||||||||||||||||
| 112 | ||||||||||||||||
| 113 | ||||||||||||||||
| 114 | ||||||||||||||||
| 115 | ||||||||||||||||
| 116 | ||||||||||||||||
| 117 | ||||||||||||||||
| 118 | ||||||||||||||||
| 119 | ||||||||||||||||
| 120 | ||||||||||||||||
| 121 | ||||||||||||||||
| 122 | ||||||||||||||||
| 123 | ||||||||||||||||
| 124 | ||||||||||||||||
| 125 | ||||||||||||||||
| 126 | ||||||||||||||||
| 127 | ||||||||||||||||
| 128 | ||||||||||||||||
| 129 | ||||||||||||||||
| 130 | ||||||||||||||||
| 131 | ||||||||||||||||
| 132 | ||||||||||||||||
| 133 | ||||||||||||||||
| 134 | ||||||||||||||||
| 135 | ||||||||||||||||
| 136 | ||||||||||||||||
| 137 | ||||||||||||||||
| 138 | ||||||||||||||||
| 139 | ||||||||||||||||
| 140 | ||||||||||||||||
| 141 | ||||||||||||||||
| 142 | ||||||||||||||||
| 143 | ||||||||||||||||
| 144 | ||||||||||||||||
| 145 | ||||||||||||||||
| 146 | ||||||||||||||||
| 147 | ||||||||||||||||
| 148 | ||||||||||||||||
| 149 | ||||||||||||||||
| 150 | ||||||||||||||||
| 151 | ||||||||||||||||
| 152 | ||||||||||||||||
| 153 | ||||||||||||||||
| 154 | ||||||||||||||||
| 155 | ||||||||||||||||
| 156 | ||||||||||||||||
| 157 | ||||||||||||||||
| 158 | ||||||||||||||||
| 159 | ||||||||||||||||
| 160 | ||||||||||||||||
| 161 | ||||||||||||||||
| 162 | ||||||||||||||||
| 163 | ||||||||||||||||
| 164 | ||||||||||||||||
| 165 | ||||||||||||||||
| 166 | ||||||||||||||||
| 167 | ||||||||||||||||
| 168 | ||||||||||||||||
| 169 | ||||||||||||||||
| 170 | ||||||||||||||||
| 171 | ||||||||||||||||
| 172 | ||||||||||||||||
| 173 | ||||||||||||||||
| 174 | ||||||||||||||||
| 175 | ||||||||||||||||
| 176 | ||||||||||||||||
| 177 | ||||||||||||||||
| 178 | ||||||||||||||||
| 179 | ||||||||||||||||
| 180 | ||||||||||||||||
| 181 | ||||||||||||||||
| 182 | ||||||||||||||||
| 183 | ||||||||||||||||
| 184 | ||||||||||||||||
| 185 | ||||||||||||||||
| 186 | ||||||||||||||||
| 187 | ||||||||||||||||
| 188 | ||||||||||||||||
| 189 | ||||||||||||||||
| 190 | ||||||||||||||||
| 191 | ||||||||||||||||
| 192 | ||||||||||||||||
| 193 | ||||||||||||||||
| 194 | ||||||||||||||||
| 195 | ||||||||||||||||
| 196 | ||||||||||||||||
| 197 | ||||||||||||||||
| 198 | ||||||||||||||||
| 199 | ||||||||||||||||
| 200 | ||||||||||||||||
| 201 | ||||||||||||||||
| 202 | ||||||||||||||||
| 203 | ||||||||||||||||
| 204 | ||||||||||||||||
| 205 | ||||||||||||||||
| 206 | ||||||||||||||||
| 207 | ||||||||||||||||
| 208 | ||||||||||||||||
| 209 | ||||||||||||||||
| 210 | ||||||||||||||||
| 211 | ||||||||||||||||
| 212 | ||||||||||||||||
| 213 | ||||||||||||||||
| 214 | ||||||||||||||||
| 215 | ||||||||||||||||
| 216 | ||||||||||||||||
| 217 | ||||||||||||||||
| 218 | ||||||||||||||||
| 219 | ||||||||||||||||
| 220 | ||||||||||||||||
| 221 | ||||||||||||||||
| 222 | ||||||||||||||||
| 223 | ||||||||||||||||
| 224 | ||||||||||||||||
| 225 | ||||||||||||||||
| 226 | ||||||||||||||||
| 227 | ||||||||||||||||
| 228 | ||||||||||||||||
| 229 | ||||||||||||||||
| 230 | ||||||||||||||||
| 231 | ||||||||||||||||
| 232 | ||||||||||||||||
| 233 | ||||||||||||||||
| 234 | ||||||||||||||||
| 235 | ||||||||||||||||
| 236 | ||||||||||||||||
| 237 | ||||||||||||||||
| 238 | ||||||||||||||||
| 239 | ||||||||||||||||
| 240 | ||||||||||||||||
| 241 | ||||||||||||||||
| 242 | ||||||||||||||||
| 243 | ||||||||||||||||
| 244 | ||||||||||||||||
| 245 | ||||||||||||||||
| 246 | (d) |
(e) |
(f) |
|||||||||||||
| 247 | (g) |
(i) |
(j) |
(k) |
||||||||||||
| 248 | (h) |
(l) |
||||||||||||||
| 36 | TOTAL |
|
|
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: LengthForStandAloneTransmissionLines |
| (b) Concept: LengthForStandAloneTransmissionLines |
| (c) Concept: LengthForStandAloneTransmissionLines |
| (d) Concept: CostOfLandAndLandRightsTransmissionLines |
| (e) Concept: ConstructionAndOtherCostsTransmissionLines |
| (f) Concept: OverallCostOfTransmissionLine |
| (g) Concept: OperatingExpensesOfTransmissionLine |
| (h) Concept: OperatingExpensesOfTransmissionLine |
| (i) Concept: MaintenanceExpensesOfTransmissionLine |
| (j) Concept: RentExpensesOfTransmissionLine |
| (k) Concept: OverallExpensesOfTransmissionLine |
| (l) Concept: OverallExpensesOfTransmissionLine |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINES ADDED DURING YEAR |
||||||||||||||||||
|
||||||||||||||||||
| LINE DESIGNATION | SUPPORTING STRUCTURE | CIRCUITS PER STRUCTURE | CONDUCTORS | LINE COST | ||||||||||||||
| Line No. |
TransmissionLineStartPoint From |
TransmissionLineEndPoint To |
LengthOfTransmissionLineAdded Line Length in Miles |
SupportingStructureOfTransmissionLineType Type |
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles |
NumberOfTransmissionCircuitsPerStructurePresent Present |
NumberOfTransmissionCircuitsPerStructureUltimate Ultimate |
ConductorSize Size |
ConductorSpecification Specification |
ConductorConfigurationAndSpacing Configuration and Spacing |
OperatingVoltageOfTransmissionLine Voltage KV (Operating) |
CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights |
CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures |
CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices |
Asset Retire. Costs |
CostOfTransmissionLinesAdded Total |
SupportingStructureConstructionType Construction |
|
|
(a) |
(b) |
(c) |
(d) |
(e) |
(f) |
(g) |
(h) |
(i) |
(j) |
(k) |
(l) |
(m) |
(n) |
(o) |
(p) |
(q) |
||
| 1 | ||||||||||||||||||
| 2 | (a) |
|||||||||||||||||
| 3 | (b) |
|||||||||||||||||
| 4 | ||||||||||||||||||
| 5 | (c) |
|||||||||||||||||
| 6 | (d) |
|||||||||||||||||
| 7 | (e) |
|||||||||||||||||
| 8 | ||||||||||||||||||
| 9 | (f) |
|||||||||||||||||
| 10 | ||||||||||||||||||
| 11 | (g) |
|||||||||||||||||
| 44 |
TOTAL |
|
|
|
|
|
|
|
|
|
||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: LengthOfTransmissionLineAdded |
| (b) Concept: LengthOfTransmissionLineAdded |
| (c) Concept: LengthOfTransmissionLineAdded |
| (d) Concept: LengthOfTransmissionLineAdded |
| (e) Concept: LengthOfTransmissionLineAdded |
| (f) Concept: LengthOfTransmissionLineAdded |
| (g) Concept: LengthOfTransmissionLineAdded |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
SUBSTATIONS |
||||||||||||
|
||||||||||||
| Character of Substation | VOLTAGE (In MVa) | Conversion Apparatus and Special Equipment | ||||||||||
| Line No. |
SubstationNameAndLocation Name and Location of Substation (a) |
SubstationCharacterDescription Transmission or Distribution (b) |
SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1) |
PrimaryVoltageLevel Primary Voltage (In MVa) (c) |
SecondaryVoltageLevel Secondary Voltage (In MVa) (d) |
TertiaryVoltageLevel Tertiary Voltage (In MVa) (e) |
SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f) |
NumberOfTransformersInService Number of Transformers In Service (g) |
Number of Spare Transformers (h) |
ConversionApparatusAndSpecialEquipmentType Type of Equipment (i) |
NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j) |
CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k) |
| 1 | ||||||||||||
| 2 | ||||||||||||
| 3 | ||||||||||||
| 4 | ||||||||||||
| 5 | ||||||||||||
| 6 | ||||||||||||
| 7 | ||||||||||||
| 8 | ||||||||||||
| 9 | ||||||||||||
| 10 | ||||||||||||
| 11 | ||||||||||||
| 12 | ||||||||||||
| 13 | ||||||||||||
| 14 | ||||||||||||
| 15 | ||||||||||||
| 16 | ||||||||||||
| 17 | ||||||||||||
| 18 | ||||||||||||
| 19 | ||||||||||||
| 20 | ||||||||||||
| 21 | ||||||||||||
| 22 | ||||||||||||
| 23 | ||||||||||||
| 24 | ||||||||||||
| 25 | ||||||||||||
| 26 | ||||||||||||
| 27 | ||||||||||||
| 28 | ||||||||||||
| 29 | ||||||||||||
| 30 | ||||||||||||
| 31 | ||||||||||||
| 32 | ||||||||||||
| 33 | ||||||||||||
| 34 | ||||||||||||
| 35 | ||||||||||||
| 36 | ||||||||||||
| 37 | ||||||||||||
| 38 | ||||||||||||
| 39 | ||||||||||||
| 40 | ||||||||||||
| 41 | ||||||||||||
| 42 | ||||||||||||
| 43 | ||||||||||||
| 44 | ||||||||||||
| 45 | ||||||||||||
| 46 | ||||||||||||
| 47 | ||||||||||||
| 48 | ||||||||||||
| 49 | ||||||||||||
| 50 | ||||||||||||
| 51 | ||||||||||||
| 52 | ||||||||||||
| 53 | ||||||||||||
| 54 | ||||||||||||
| 55 | ||||||||||||
| 56 | ||||||||||||
| 57 | ||||||||||||
| 58 | ||||||||||||
| 59 | ||||||||||||
| 60 | ||||||||||||
| 61 | ||||||||||||
| 62 | ||||||||||||
| 63 | ||||||||||||
| 64 | ||||||||||||
| 65 | ||||||||||||
| 66 | ||||||||||||
| 67 | ||||||||||||
| 68 | ||||||||||||
| 69 | ||||||||||||
| 70 | ||||||||||||
| 71 | ||||||||||||
| 72 | ||||||||||||
| 73 | ||||||||||||
| 74 | ||||||||||||
| 75 | ||||||||||||
| 76 | ||||||||||||
| 77 | ||||||||||||
| 78 | ||||||||||||
| 79 | ||||||||||||
| 80 | ||||||||||||
| 81 | ||||||||||||
| 82 | ||||||||||||
| 83 | ||||||||||||
| 84 | ||||||||||||
| 85 | ||||||||||||
| 86 | ||||||||||||
| 87 | ||||||||||||
| 88 | ||||||||||||
| 89 | ||||||||||||
| 90 | ||||||||||||
| 91 | ||||||||||||
| 92 | ||||||||||||
| 93 | ||||||||||||
| 94 | ||||||||||||
| 95 | ||||||||||||
| 96 | ||||||||||||
| 97 | ||||||||||||
| 98 | ||||||||||||
| 99 | ||||||||||||
| 100 | ||||||||||||
| 101 | ||||||||||||
| 102 | ||||||||||||
| 103 | ||||||||||||
| 104 | ||||||||||||
| 105 | ||||||||||||
| 106 | ||||||||||||
| 107 | ||||||||||||
| 108 | ||||||||||||
| 109 | ||||||||||||
| 110 | ||||||||||||
| 111 | ||||||||||||
| 112 | ||||||||||||
| 113 | ||||||||||||
| 114 | ||||||||||||
| 115 | ||||||||||||
| 116 | ||||||||||||
| 117 | ||||||||||||
| 118 | ||||||||||||
| 119 | ||||||||||||
| 120 | ||||||||||||
| 121 | ||||||||||||
| 122 | ||||||||||||
| 123 | ||||||||||||
| 124 | ||||||||||||
| 125 | ||||||||||||
| 126 | ||||||||||||
| 127 | ||||||||||||
| 128 | ||||||||||||
| 129 | ||||||||||||
| 130 | ||||||||||||
| 131 | ||||||||||||
| 132 | ||||||||||||
| 133 | ||||||||||||
| 134 | ||||||||||||
| 135 | ||||||||||||
| 136 | ||||||||||||
| 137 | ||||||||||||
| 138 | ||||||||||||
| 139 | ||||||||||||
| 140 | ||||||||||||
| 141 | ||||||||||||
| 142 | ||||||||||||
| 143 | ||||||||||||
| 144 | ||||||||||||
| 145 | ||||||||||||
| 146 | ||||||||||||
| 147 | ||||||||||||
| 148 | ||||||||||||
| 149 | ||||||||||||
| 150 | ||||||||||||
| 151 | ||||||||||||
| 152 | ||||||||||||
| 153 | ||||||||||||
| 154 | ||||||||||||
| 155 | ||||||||||||
| 156 | ||||||||||||
| 157 | ||||||||||||
| 158 | ||||||||||||
| 159 | ||||||||||||
| 160 | ||||||||||||
| 161 | ||||||||||||
| 162 | ||||||||||||
| 163 | ||||||||||||
| 164 | ||||||||||||
| 165 | ||||||||||||
| 166 | ||||||||||||
| 167 | ||||||||||||
| 168 | ||||||||||||
| 169 | Total |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES |
||||
|
||||
| Line No. |
Description of the Good or Service (a) |
Name of Associated/Affiliated Company (b) |
Account(s) Charged or Credited (c) |
Amount Charged or Credited (d) |
| 1 |
Non-power Goods or Services Provided by Affiliated |
|||
| 2 | (a) |
|||
| 3 | ||||
| 4 | ||||
| 5 | ||||
| 6 | ||||
| 7 | ||||
| 8 | ||||
| 9 | ||||
| 10 | ||||
| 11 | ||||
| 12 | ||||
| 13 | ||||
| 14 | ||||
| 15 | ||||
| 16 | ||||
| 17 | ||||
| 18 | ||||
| 19 | ||||
| 20 | ||||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
| 28 | ||||
| 29 | ||||
| 30 | ||||
| 31 | ||||
| 32 | ||||
| 33 | ||||
| 34 | ||||
| 35 | ||||
| 36 | ||||
| 37 | ||||
| 38 | ||||
| 39 | ||||
| 40 | ||||
| 41 | ||||
| 42 | ||||
| 43 | ||||
| 44 | ||||
| 45 | ||||
| 46 | ||||
| 47 | ||||
| 48 | ||||
| 49 | ||||
| 50 | ||||
| 51 | ||||
| 52 | ||||
| 53 | ||||
| 54 | ||||
| 55 | ||||
| 56 | ||||
| 57 | ||||
| 58 | ||||
| 59 | ||||
| 60 | ||||
| 61 | ||||
| 62 | ||||
| 63 | ||||
| 64 | ||||
| 65 | ||||
| 66 | ||||
| 67 | ||||
| 68 | ||||
| 69 | ||||
| 70 | ||||
| 71 | ||||
| 72 | ||||
| 73 | ||||
| 74 | ||||
| 75 | ||||
| 76 | ||||
| 77 | ||||
| 78 | ||||
| 79 | ||||
| 80 | ||||
| 81 | ||||
| 82 | ||||
| 83 | ||||
| 84 | ||||
| 85 | ||||
| 86 | ||||
| 87 | ||||
| 88 | ||||
| 89 | ||||
| 90 | ||||
| 91 | ||||
| 92 | ||||
| 93 | ||||
| 94 | ||||
| 95 | ||||
| 96 | ||||
| 97 | ||||
| 98 | ||||
| 99 | ||||
| 100 | ||||
| 101 | ||||
| 102 | ||||
| 103 | ||||
| 104 | ||||
| 105 | ||||
| 106 | ||||
| 107 | ||||
| 108 | ||||
| 109 | ||||
| 110 | ||||
| 111 | ||||
| 19 | ||||
| 20 |
Non-power Goods or Services Provided for Affiliated |
|||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
| 28 | ||||
| 29 | ||||
| 30 | ||||
| 31 | ||||
| 32 | ||||
| 33 | ||||
| 34 | ||||
| 35 | ||||
| 36 | ||||
| 37 | ||||
| 38 | ||||
| 39 | ||||
| 40 | ||||
| 41 | ||||
| 42 | ||||
| 43 | ||||
| 44 | ||||
| 45 | ||||
| 46 | ||||
| 47 | ||||
| 42 | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DueToOrChargedByTheTransactionsWithAssociatedAffiliatedCompanies |
All non-power goods and services provided by affiliated companies are billed to San Diego Gas and Electric at fully loaded cost.
(Rows 2-19, 43-60, 83-100, 123-138)
Fully loaded costs include all direct expenses, indirect overheads and shared service billing. Shared service non‑power goods and service support cost are based on allocation process methodologies for Sempra Energy Corporate Center cost centers. The following information regarding multi‑factor and causal‑beneficial relationship information was provided by the Sempra Energy Corporate Center Budget and Reporting Manager and is a summary of the varying methodologies used:
•
Multi‑factor basic, also known as "Four‑Factor", this method is used by a department for which there is no causal relationship. The Multi‑factor basic weights four factors equally for each business unit: Revenues, Operating Expenses, Gross Plant and Investment, and Employees
•
Multi‑factor basic without ONCOR, also known as "Four‑Factor", this method is used by a department for which there is no causal relationship. The Multi‑factor basic weights four factors equally for each business unit: Revenues, Operating Expenses, Gross Plant and Investment, and Employees (EXCLUDES ONCOR)
•
Multi‑factor Utility, this method uses the same four factors that appear in Multi‑factor (basic), but calculates ratios for California utility business units only
•
Multi‑factor split, this method divides costs 50% to Utilities, 50% to Global. The Multi‑factor (basic) percentages are the basis for the allocation between Southern California Gas Company and San Diego Gas and Electric, and between Global Business Units
•
Multi‑factor split without ONCOR, this method divides costs 50% to Utilities, 50% to Global. The Multi‑factor (basic) percentages are the basis for the allocation between Southern California Gas Company and San Diego Gas and Electric, and between Global Business Units (EXCLUDES ONCOR)
•
5 executive cost centers allocated using the weighted average of the annual labor budget for departments that report to the respective executive
•
Causal - Executive Security, this method accounts for the transportation services available to Corporate officers and considers their allocation methods in general. The CEO (retained) has one dedicated driver, while the other 3 drivers are available to other executives and assumes an even allocation of Utility, Global and additional retained. The result is 25% Utility, 25% Global and 50% Retained for 4 drivers
•
Causal – Fire Insurance, this method allocates all costs for Fire Insurance based on miles of electrical lines per business unit
•
Causal – Full Time Employee Equivalents, total Full Time Employee equivalents (FTE’s) are used as the basis for allocation of most Human Resource departmental services provided on behalf of all the business units. The Sempra Energy Corporate Center FTE’s are re‑allocated by Multi‑factor (basic) to result in a blended rate
•
Causal – Executive Full Time Employee Equivalents, this method allocated the support and administration cost for executive related services using a weighted average of participating officers. Executives are heavily weighted (75%) compared to Directors and Vice Presidents (25%). The Sempra Energy Corporate Center shared service Executives are then Multi‑factored (basic) resulting in a blended percentage
•
Causal – My Info Services Contract, My Info services cost is allocated by the number of people in the My Info system. The portion of services attributable to Sempra Energy Corporate Center amount is then re‑allocated by Multi‑factor (basic) to result in a blended percentage
•
Causal – Headquarter Security, this method allocates the costs of Sempra Energy Corporate Center security, excluding the Headquarter guard service contract, by the Causal - Full Time Employee Equivalent method, and allocates the Headquarter guard service contract by the ratio of employees occupying the Sempra Energy Corporate Center Headquarter building
•
Causal – Tax Services, this allocation is a weighted average of the workload of each employee within the Tax department based on an annual time study. The Sempra Energy Corporate Center workload hours are re‑allocated using Multi‑factor (basic) resulting in a blended percentage
•
Causal – Hyperion Financial Management and Consolidation System, this allocation is a weighted average of the headcount of Hyperion Financial Management and Consolidation System users. The Sempra Energy Corporate Center amount is then re‑allocated by Multi‑factor (basic) to result in a blended percentage for each business unit
•
Causal – FLP (Financial Leadership Program), this allocation is a weighted average of the employees in the Financial Leadership Program based on the business units they support. The Sempra Energy Corporate Center workload is then re‑allocated by Multi‑factor (basic) to result in a blended percentage
•
Causal - Citizenship Engagement, this method uses the Multi-Factor Basic allocation as a starting point, then reduces the percentages to exclude a portion attributed to managing costs which are retained
•
Causal – Global Risk, Energy Risk Management estimates the percentage of hours worked on both market risk (energy risk and Dodd Frank) and the credit risk by business unit
•
Causal – Group Executive Insurance, this method allocates the group executive insurance policy using a weighted average of covered officers, per their assigned business unit. The Sempra Energy Corporate Center FTE’s are reallocated by multi-factors
•
Causal – Pension, this method allocates based on the summary value of Sempra Energy’s major pension savings funds and San Diego Gas & Electric’s Nuclear Decommissioning Trust (NDT). The Sempra Energy Corporate Center and Sempra Global value is then re-allocated by the US-based FTE’s, with Sempra Energy Corporate Center FTE’s further re-allocated based on Multi‑factor (basic)
•
Causal – Treasury, for the Finance department, the Assistant Treasurer estimates percentages of effort for the business units based on significant projects requiring financing or advisory work
•
Causal – Law Department, this allocation method is based on direct time charged by attorneys, paralegal and law clerks in the Archer timekeeping system during the previous Jan-Sep period. Hours for Sempra Energy Corporate Center are re-allocated by Multi-Factor Basic, resulting in a blended percentage
•
Causal – Audit Plan, this method is based on the Audit hours planned for each business unit in the coming year. The portion of services attributable to Sempra Energy Corporate Center is re-allocated using Multi-Factor basic method to result in a blended percentage for each business unit
•
Causal – SOX, this allocation is a weighted average of the workload of each employee within SOX Compliance based on an annual time study. Sempra Energy Corporate Center workload hours are reallocated using Multi-Factor Basic, resulting in a blended percentage
•
Causal – Bank Reconciliations and Escheatment, for the Bank Reconciliation and Escheatment department, the estimated percentages of effort for the business units based on the bank reconciliation and escheatment activity for the upcoming period
•
Causal – Security Services, this method accounts for the call-in transportation services available to Corporate Officers and Executives. These call-in services are primarily provided to Corporate Officers and Executives at the California Utilities and for Mexico and South America. Occasionally, these services may be provided to Officers and Executives in other business units or at Sempra Energy Corporate Center. In this instance, these costs will be directly charged to the respective business unit or retained at Sempra Energy Corporate Center
•
Causal – Sempra HQ CSOC Depreciation, needs to be allocated by this method, San Diego Gas & Electric 72.7% other affiliates 25.9%
•
Causal – Sacramento Office Depreciation, needs to be allocated by this method, San Diego Gas & Electric 50%, other affiliates 50%
•
Causal - VP Tax, this allocation is a weighted average of the workload of each employee within the Tax department based on an annual time study. Parent workload hours are reallocated using Multi-Factor Basic, resulting in a blended percentage
•
Causal – Cash Management, for the Cash Management department, the Director estimates percentages based on volumes and time involved in the business units funding activities
•
Causal – Executive Benefits (Southern California Gas Company), direct restricted stock and stock options expense for Southern California Gas Company executives is allocated because some executives are shared by more than one business unit. The percentages reflect a weighted average of each executive's work distribution among business units
•
Causal – Executive Benefits (San Diego Gas and Electric), direct restricted stock and stock options expense for San Diego Gas and Electric executives is allocated because some executives are shared by more than one business unit. The percentages reflect a weighted average of each executive's work distribution among business units
Shared asset allocation of depreciation expense associated with capitalized assets at each shared service entity are allocated uniquely depending on its allocation of benefit or supporting purpose, and follow as such:
•
Causal – HQ Depreciation – depreciation expense & ROR related to "HQ leasehold improvements" is allocated based on the square footage directly occupied by the business units. Corporate Center's direct occupation except for the portion which is retained, is re-allocated based on the Multi-Factor base allocation
•
Causal - CCURE System, this allocation is a weighted average of the number of card readers used per business unit for depreciation of the CCURE 9000 Security System. Sempra Energy Corporate Center units are reallocated using Multi-factor Basic, resulting in a blended percentage
•
Causal – Headquarters Occupancy, Rent, depreciation & ROR related to new headquarters that is allocated based on the square footage directly occupied by the business units. Sempra Energy Corporate Center’s direct occupation, except for an executive portion which is retained, is reallocated based on the Multi-Factor Basic. Amenity floors in the HQ are excluded, as they benefit all occupants ratably
(Rows 163-180, 203-220, 243-244)
Fully loaded costs include all direct expenses, indirect overheads and shared service billing. Shared service non-power goods and service support cost are based on allocation process methodologies for 133 Southern California Gas Company cost centers. The following causal beneficial relationship information is a summary of the 22 varying methodologies used:
•
29 cost centers used a form of LAN ID counts to determine the shared allocation
•
28 cost centers used a ratio of miles to pipe
•
12 cost centers used a form of weighted average allocation of time by inherent knowledge of the manager/planner assessment within the cost center department
•
9 cost centers used a form of allocation of computer and/or server system and resource usage statistics
•
8 cost centers used a form of prior year project assignments as a base for the current year distribution, which is adjusted as necessary when current year projects begin or change and impact the current allocation
•
7 cost centers used a form of departmental studies based on current year budgeted activities and/or dollars
•
7 cost centers used a form of the existing current year Sempra Energy Corporate Center four factor multi factor allocation which includes weighted averages of operating revenue, operating expenses, gross plant and investment and Full Time Employee equivalent numbers
•
6 cost centers used a form of gas meter counts and service territory allocations
•
5 cost centers used a form of a ratio of horsepower in compressor engines in the service territory
•
5 cost centers used a form of Full Time Employee equivalent statistics for support
•
3 cost centers used a study based on cases worked by both regulated and non-regulated companies
•
2 cost centers used a form of an allocation of space study identifying building square footage assigned
•
2 cost centers used a study based on volumes of items mailed and payments processed and the allocation of employee time
•
2 cost centers used a form of allocation based on gas flow throughput
There was one use by a cost center of each of the remaining allocation methodologies: Communication by stakeholders
•
An employee matrix
•
Call volume
•
Claims processed over a five-year period
•
A meter ratio applied to specific budgeted activity
•
A mileage ratio applied to specific budgeted activity
•
The number of network sites
•
The number of SAP ID’s
•
A workload distribution study
(Row 21-42, 61-65)
All non‑power goods and services provided by San Diego Gas and Electric are billed at fully loaded cost.
(Row 21)
Affiliate companies charged by San Diego Gas and Electric for less than $250,000 include: Sempra International South America, Sempra International Mexico.
(Rows 21-42, 61-65)
Fully loaded costs include all direct expenses, indirect overheads and, where applicable, a labor premium required by the Enova/Pacific Enterprises Merger Decision (D.98‑03‑073) for shared service billing. The Merger Decision also requires San Diego Gas and Electric to charge employee transfer fees to an affiliated company. Shared service non‑power goods and service support cost are based on allocation process methodologies for 112 San Diego Gas and Electric cost centers. The following causal‑beneficial relationship information is a summary of the 19 varying methodologies used:
•
37 cost centers used a form of LAN ID counts to determine the shared allocation
•
19 cost centers used a form of weighted average allocation of time by inherent knowledge of the manager/planner assessment within the cost center department
•
17 cost centers used a form of an allocation of space study identifying building square footage assigned
•
9 cost centers used a form of prior year project assignments as a base for the current year distribution, which is adjusted as necessary when current year projects begin or change and impact the current allocation
•
8 cost centers use a form of workload distribution study
•
4 cost centers used the existing current year Sempra Energy Corporate Center four factor multi‑factor allocation which includes weighted averages of operating revenue, operating expenses, gross plant and investment and Full Time Employee equivalent numbers
•
3 cost centers used a form of budgeted current year project assignments
•
2 cost centers were charged 100% to Sempra Energy Corporate Center
•
2 cost centers used a form of a count of network sites
•
2 cost centers used a form of the number of contracts supported
There was one use by a cost center of each of the remaining allocation methodologies:
•
An allocation of time by Vice President or Director’s assessment of planned current year project assignments within the cost center, which is adjusted as necessary when current year projects begin or change and impact the current allocation and current years budgeted activities by Affiliate
•
Archibus transactional data for Facilities work requests and projects
•
A unit of measure based on San Diego Gas & Electric and Southern California Gas call volume
•
Based on the number of MYINFO user accounts
•
A form of Full Time Employee equivalent statistics for support
•
The number of full-time equivalent employees benefited by the activity
•
The number of SAP ID’s
•
A form of allocation of computer and/or server system and resource usage statistics
•
An allocation based on the number of applications used for DevSecOps
|